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Home My WebLink About195-106XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: ;e Dianna TO RE-SCAN Vincent Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl .. STATE OF ALASKA _ ALAS~L AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: D Oil DGas D Plugged 181 Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 3/5/2006 195-106 305-079 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 08/16/1995 50-029-22576-00-00 4a. Location of Well (Governmental Section): 7. Date ToO. Reached 14. Well Name and Number: Surface: 08/28/1995 PBU P2-37 287' SNL, 1342' EWL, SEC. 14, T12N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2424' SNL, 5162' EWL, SEC. 13, T12N, R14E, UM 52.1' Prudhoe Bay Field I Point Mclntyn Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2482' SNL, 161' EWL, SEC. 18, T12N, R15E, UM 13731 + 9135 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 681585 y- 5998297 Zone- ASP4 13815 + 9184 Ft ADL 034627 ~--~ 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 690736 y- 5996388 Zone- ASP4 ~. --- N/A MD Total Depth: x- 691017 y- 5996336 Zone- ASP4 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes 181 No N/A MSL 1900' (Approx.) 21. Logs Run: GR I NEU I DEN 122. GASING, LINER AND CEMENTING RECORD I ><8~f¿~G .·.~ETfIIllGDEPTHMIi . SETTINGDEPTf\'1VO i~fit ........ < :.Y Wr.b'=;" i:",' GRAOE ~ .> i '. ..... h...~.. .,. lOP. tiOTTOM Top BOTTOM 20" 94# H-40 Surface 80' Surface 80' 30" 250 sx Arcticset (Approx.) 10-3/4" 45.5# NT80LHE 40' 4621' 40' 3719' 13-1/2" 1130 sx PF 'E', 375 sx Class 'G' 7-518" 29.7# USS95/ NT13Cr80 38' 13810' 38' 9181' 9-7/8" 485 sx Class 'G' 23. Perforations open. to Production (MD + TVD of Top and 24, . "T ...~:..... .... '>" .... .........' <>....../<> '.. )1311'1\:i Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, 13Cr 13151' 13095' MD TVD MD TVD 125. . ···.·i-,ð.Q![)}.... . "'Th.<·«· i. iC<IY/. ......... <.....> (~f·:. ¡..,~k·¡'·l: ( .. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ..t_ '" ",... "...... 13476' Set Whipstock 13476' ~bandon wI 12 Bbls Cement " 26. PRODUCTION TEST . './ '.. ..J/" d'1 ,/ t·, J" Date First Production: Method of Operation (Flowing, Gas Lift, etc.): .h..... f,y} Not on Production N/A ( ¿~/n, Date of Test Hours Tested PRODUCTION FOR OIL-BSL GAs-McF W A TER-BSL ~~EfSIZ~ GAS-'OÚ::, RATIO TEST PERIOD + .i>..; .....".>,.. Flow Tubing Casing Pressure CALCULATED + OIL-BsL GAs-McF WATER-BSL OIL GRAVITY:,A\P}(CpRR)Jj " .' 'i Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS 8Ft APR 2 8 2006 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE G 28. GEOLOGIC MARKE 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kalubik 13385' 8930' None Kuparuk River 13462' 8976' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date Cf-/ (2IÞ / ð<.o PBU P2-37 Well Number 195-106 305-079 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mary Endacott, 564-4388 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . . Well: Field: API: Permit: P2-37A Prudhoe Bay Unit 50-029-22576-01-00 205-057 Accept: Spud: Release: Rig: 03/01/06 03/09/06 03/18/06 Nordic #1 ".~... u'u 'u'C· .... ;~"n.~"'~M'''u'' PRE-RIG WORK 01/04/06 DRIFTED WI 3.80 CENT AND SAMPLE BAILER TO 12,169' SLM; SAMPLE OF HYDRATES. DRIFTED WI 3.625 SWEDGE AND SAMPLE BAILER TO 12,893' SLM. SAMPLE OF HYDRATES. RDMO. 02/14/06 MU/RIH WI WEATHERFORD 27/8" MOTOR AND 3.8" JUNK MILL. MILL FROM SURFACE TO 6280'. 02/15/06 MILLING WI WEATHERFORD 2 718" MOTOR, 3.8" JUNK MILL FROM 6280'. MOTOR WORK AND 9 STALLS FROM 12447' -13100'. PUMP FLOPRO SWEEPS. BACK REAM I REPEAT PASSES FROM 12400' -13100'. PUMP FINAL FLOPRO SWEEP AT 13100', CHASE TO SURFACE. FP COIL. MUIRIH WI 2.875" UR (BLADES OPEN TO 6.75"). RIH AND TAG HARD AT 13097'. ATTEMPT TO SPIN THROUGH UNSUCCESSFULLY. POOH. MU LEFT HANDED 2 7/8" MOTOR AND 3.8" DS MILL. 02/16/06 RIH WI 3.8" DSM. BEGIN MILLING FROM 12000'. MILL OUT XN AT 13129' WITH 3.80". RUN MILL TO 13550' WI REPEATS ACROSS AREAS OF WORK. POOH. RIH WITH BOT DB UNDEREAMER WITH THREE BLADES EXPANDABLE TO 6.10" OD. WORK THROUGH BOTTOM GLM. INCREASE LIFT GAS RATE TO 3MM AND STARTING UNDEREAMING FROM 13180' DOWN TO 13550' CTM. PICK UP TO 13400' AND WORK BACK DOWN TO 13550' ONE MORE TIME TO INSURE AREA OF INTEREST CLEAN. CHASE OUT WITH 10 BBLS FLO PRO. MU 3" IBP. BLOW IA DOWN THROUGH FLOWLINE. KILL WELL WI 340 BBL KCL. RIH WI IBP. 02/17/06 RIH WI 3" IBP ON CHROME COIL. MAKE DEPTH SHIFT WI TEL. SET IBP AT 13118'. ATTEMPT TO PERFORM MIT OA. 5 LOCKDOWN SCREWS LEAKING, SUSPEND TEST UNTIL LDS'S TIGHTENED DOWN TO PROPER TORQUE. DHD TIGHTENS SCREWS. RE TEST MIT OA. POOH. LDS'S LEAK AGAIN AT 1790 PSI, CANCEL TEST AND FLAG LEAKING ONES. RETIGHTEN SCREW. PERFORM MIT-T TO 3000 PSI. PASSED. CIRC IA AND TBG TO CRUDE. PERFORM CMIT TO 3000 PSI. PASSED RULE 1/FAILED RULES 2 AND3. 02/18/06 RE-TEST CMIT (#2). PASSED OK. RIH WI BAKER FISHING STRING. TAG IBP AT 13111'. LATCH I RELEASE FISH. POOH. FP BACKSIDE. FP FLOWLINE WITH 10 BBLS NEAT METHANOL PER OPERATORS REQUEST. RECOVER IBP. RECOVER ALL RUBBERS. RD. SECURE LOCATION. 02/24/06 RUN FLAPPER CHECKER DRIFT, CALIPER TUBING. 02/25/06 CALIPER CASING AND TUBING FROM 13600' SLM. DRIFT WI 3.70 CENT, 20' OF 3 3/8 DG, SAT DOWN AT 13366'. Page 1 .. BP EXPLORATION .Op~~ªtions SummaryA~p~..t Start: 2/27/2006 Rig Release: 3/18/2006 Rig Number: N1 ~~as=J Description of Operations PRE I SAFETY MEETING. Held pre rig move meeting with all I personnel. Reviewed rig rnove plan and hazards. i Moved rig to P2 pad with no incidents. Rig on standby while waiting for well and location prep. Removed wellhouse and flowline. Surveyed rig footprint area. Wait on Veco to grade location level for rig footprint. Rig on standby while waiting for Veco to arrive on location. Iveco graded location level for rig footprint. I Survey location again for level. Little Red on location attempt to kill well with 4% Bio and pressure test OA.Tubing pressure 250 psi. Back up to well Tubing pressure 450 psi. Close SSSV. Back over well. ACCEPT RIG AT 12:00 HRS. I N/U BOPE. General rig up of tanks, trailers and hardline. Test BOPE. Test witnessed by BP WSL Rick Whitlow, AOGCC witness waived by Inspecter Jeff Jones. Send test report to AOGCC. Pump 5 bbls methanol, insert dart, displace dart with KCI water. Dart on seat at 57.7 bbls. Pump open SSV and SSSV. Hold 4500 psi on SSSV. SIWHP = 320 psi. Kill well with 9.7 ppg Brine 1 Biozan. Pump 2.9 bpm at 2080 psi. Pump 220 bbls. Monitor well. Well is dead. M/U BHA #1, U/R BHA with BOT DB UR with 6.81' blades. OAL = 52.95', RIH with UR BHA. Run SWS CT Inspect on coil on trip in hole. RIH at 80 fpm. Start reeming operation at 13421 CT measured. .6 bpm at 1700 psi, increase rate to 1.29 bpm at 4000. RIH13422.4 Cutter pressure fell to 3OO0psi. Knives open, Increase rate to 1.81 @ 3600 psi. Ream at 1 ft/min PU, 48.5 K Up WI. Underreeming at 1.9 bpm at 1700 psi .2ft/min. establish pattern increase rate to 2.3 @ 2290 psi. time ream down at .2 ft/min. Ream down at 10 fph to prevent stalling. Had total of 5 stalls to get started. UR with 2.4 bpm, 2600 psi. No stalls at 10 fph. Last stall at 13,465'. UR down to 13522' at 10 fph. Take scale samples every 10', Backream up to 13450' at 5 fpm. 46K up wt. UR down at 1 fpm, 2.5 bpm, 2800 psi, 5K down wt. UR down to 13522'. No stalls or motor work. Pull up into tubing with no pump, no overpull. Pull to 13050'. RIH to 13470'. Insert 3/4' steel ball and displace to circ sub. Ream down while circ. Ball on seat at 51 bbls. Increase pump up to 3 bpm. POH while circ thru circ sub at 3 bpm, 2900 psi. Layout underreaming BHA, underreamer blades appeared full open while underreaming, based on wear. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-37 P2-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From- To Hours Task Code NPT 2/28/2006 I 02:00 - 02:30 I 0.50 MOB P I I 02:30 - 12:00 9.50 MOB P 12:00 - 00:00 12.00 MOB N WAIT PRE PRE 3/1/2006 00:00 - 02:00 02:00 - 12:00 2.00 MOB 10.00 MOB N N WAIT PRE WAIT PRE 12:00 - 16:00 4.00 RIGU P PRE 16:00 - 00:00 8.00 BOPSU P PRE 3/2/2006 00:00 - 01 :00 1.00 BOPSU P PRE 01 :00 - 04:00 3.00 KILL P 04:00 - 04:40 0.67 CLEAN P 04:40 - 08:00 3.33 CLEAN P 08:00 - 19:00 11.00 CLEAN P PRE PRE PRE PRE 19:00 - 21 :30 2.50 CLEAN P PRE 21 :30 - 22:00 0.50 CLEAN P PRE 3/3/2006 22:00 - 00:00 00:00 - 00:45 PRE PRE 2.00 CLEAN P 0.75 CLEAN P Spud Date: 8/16/1995 End: 3/18/2006 Printed: 312012006 12:12:00 PM Page 2 ... BP EXPLORATION Operations Summary Report SAFETY MEETING - reviewed procedure, hazards and mitigation to make-up and run slickline PDS caliper logging BHA and durnrny WS. M/U PDS caliper logging BHA on slickline. RIH wI PDS caliper. Sat down at 13,200'. Unable to get any deeper. POH. M/U dummy whipstock BHA with 18' x 3.625" dummy whipstock to drift hole. RIH with 3.6" x 18 ft dumrny whipstock on S-line. . NO GO at 12225' which is in the tubing. Had to jar free. Seen 450 -650# drag for the first 300', POH No debris or damage to tool. RIH with bailer. Clear at 12225 but set down at 13211'. Hard set down no over pull. POH. Bailer recovered a couple finger tip sized pieced of asphalstine imbedded with some form of carbonite possibly Barium Carbonite (Witherite). Release S- line. DPRB PRE PU cleanout assy with four 3.625" O.D. weight bars to sirnulate whipstock length and stiffness. DPRB PRE RIH to 13520. No problems No motor work. PU to tail pipe. Circulate 30 bbl hi vis pill. Chase pill to surface. Got about 20 gal of high weight scale I metal on shaker. POH while pumping 3bpm. Layout BHA. Well is dead. SSSV press = 4600 psi. Rig up SWS Sline unit. M/U 3.6" x 18' dummy whipstock on Sline tools. PJSM for S-line dummy WS run. Continue M/U dummy WS BHA on S-line. Continue dummy WS run on Sline. Sit down 3 times at 13,211', just below tailpipe. Jar down and then need to jar upwards to free. 600# overpull off bottom. POOH. POOH with dummy whipstock. Rig down Sline unit. Not able to run whipstock on E-Line. Will deploy it on CT with BHI tools and BOT FAIV. Will run Memory GR/CCL first to flag coil for depth control. WEXIT Cut 50' for chrome mgmtl M/U coil connector and P-test WEXIT PJSM to pick up and run memory GR/CCL tool with BHI mud-pulse tools and BOT FAIV. Plan to shallow depth test Baker tools and proceed to flag pipe based on tubing jewelry near tubing tail. Prep for setting WS on coil. WEXIT M/U SLB memory GR/CCL with BHI mud-pulse tools and BOT FAIV. WEXIT RIH to 3000 TEST Baker MWD Rate Pressure on/off 1.6 1700 off 1.8 2370 yes pulsing 2.0 2644 drop to 1400 psi good downlink.5 hertz data rate 2.0 2900 drop to 1500 psi good down link .5 hertz data rate 2.15 2950 drop to 1700 psi good down link .36 hertz data rate This is the max design data transmittion rate. This is the time it takes to transmit one bite of information. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-37 P2-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code NPT Phase 3/3/2006 00:45 - 01 :00 0.25 CLEAN P PRE 01 :00 . 01 :45 0.75 CLEAN P PRE :45 - 05:30 3.75 CLEAN P PRE 05:30 . 05:50 0.33 CLEAN P PRE 05:50 - 13:00 7.17 CLEAN P PRE 13:00 - 13:30 0.50 CLEAN N 13:30 - 20:00 6.50 CLEAN N 20:00 - 21 :00 1.00 CLEAN N DPRB PRE 21 :00 - 23:00 2.00 CLEAN N DPRB PRE 23:00 - 23:15 0.25 CLEAN N DPRB PRE 23:15 - 00:00 0.75 CLEAN N DPRB PRE 3/4/2006 00:00 - 02:00 2.00 CLEAN N DPRB PRE 02:00 - 04:00 2.00 CLEAN N DPRB PRE 04:00 - 04:45 04:45 - 05:00 0.75 WHIP P 0.25 WHIP P 05:00 - 06:30 1.50 WHIP P 06:30 - 07:50 1.33 WHIP P Start: 2/27/2006 Rig Release: 3/18/2006 Rig Number: N1 Spud Date: 8/16/1995 End: 3/18/2006 Description of Operations Printed: 3/2012006 12:12:00 PM BP EXPLORATION Operations Su ary Report Page 3 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-37 P2-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/27/2006 Rig Release: 3/18/2006 Rig Number: N1 Spud Date: 8/16/1995 End: 3/18/2006 Date From - To Hours Task Code NPT Phase Description of Operations 3/4/2006 06:30 - 07:50 1.33 WHIP P WEXIT Will check to see if FAIV armed once back to surface. FAIV arms theoritically at 2.3 bpm. 07:50 - 09:00 1.17 WHIP P WEXIT Continue to RIH to 12000'. Circulating at 1.2 bprn @ 1200 psi. 09:00 - 09:50 0.83 WHIP P WEXIT LOG 12000 to 12520 at 30 ft/min. Flagg at 13400 EOP. 09:50 - 10:45 0.92 WHIP P WEXIT Log frorn 12520 to 11100 @ 60 ft/min. Log 11100 to 11000 @ 600 ft/hr. 10:45 - 11 :00 0.25 WHIP P WEXIT POH at 1.2 bprn @ 1050 psi. 11 :00 - 11 :20 0.33 WHIP P WEXIT LOG down 11200 to 11350 2.2 bpm 3530 psi to acquire MWD GR data for cornparitive purpose. 11 :20 - 11 :55 0.58 WHIP P WEXIT POH to surface circulating 1.1 bpm at 870 psi. 11 :55 - 12:40 0.75 WHIP P WEXIT Replace bearing in Goose neck. 12:40 - 14:00 1.33 WHIP P IWEXIT POH to 200'. Confirm the FAIV was not armed. Shut down iWEXIT pump and restart pump. Broke circulation. POH. 14:00 - 16:00 2.00 WHIP P LD BHA and memory tool. Correction to flag =+4'. FAIV ports I showed signs of washing out. Lesson learned circulation in and I out at 1.2 bpm washed out ports. Secondly the shear screws in FAIV partially sheared. We were close to activating FAIV. UP Baker whipstock and new FAIV. 16:00 - 16:10 0.17 WHIP P WEXIT Stab onto well. Circulate 1.8 bpm at 2900 psi.to check MWD. Shut Down FAIV activated. 16:10 - 17:30 1.33 WHIP P WEXIT Stab off well. Redress FAIV. Stab onto well. 17:30 - 21 :00 3.50 WHIP P WEXIT RIH with WS. 21:00 - 21:15 0.25 WHIP P WEXIT Correct to flag, reset to 13494.3'. 21 :15 - 21 :30 0.25 WHIP P ¡WEXIT P/U to 13489.6(bottom of string). WS length 17.53ft. Orient to 21 degrees ROHS. BHI tools working well at 2.1 bpm. Pressure up to 4300psi (2.5 bpm) to arm FAIV. Release WS. TOWS at 13472'. Pick-up and set down 2k# to confirm placement. 21 :30 - 00:00 2.50 WHIP P WEXIT POOH to lay down WS setting BHA. 3/5/2006 00:00 - 00:15 0.25 WHIP P WEXIT Continue POOH w WS setting tools. 00:15 - 01:15 1.00 WHIP P WEXIT ooH - lay down tools. Pick up cementing nozzle. 01:15 - 04:00 2.75 WHIP P WEXIT RIH to abandon perfs and lay in cement to above TOWS. Tagged 2k# at 13487'. 04:00 - 04:15 0.25 WHIP P WEXIT Perform injectivity test. Hole took no fluid at 1000psi. 04:15 - 04:30 0.25 WHIP P WEXIT PJSM for cementing - lay in to abandon perfs and support whipstock. 04:30 - 05:00 0.50 WHIP P WEXIT R/U cementers. 05:00 - 06:30 1.50 WHIP P WEXIT Pick-up to 13440'. Pump 15 bbls 9.7 brine, 2 bbls fresh water, 12 bbls 15.8ppb unislurry cement, 2 bbls of water and 15 bbls brine. WCTOC 12600'. P/U to 12300' and wait for cement to swap prior to cleanout with 1.5ppb biozan. 06:30 - 09:00 2.50 WHIP P WEXIT RIH to WS circulating 2.73 bpm at 2750 psi. . Seeing pressure increase indicating in cement at 12800'. wash to WS at 13486. POH 09:00 - 11 :15 2.25 WHIP P WEXIT POH. 11 :15 - 12:00 0.75 WHIP P WEXIT Flush stack 12:00 - 12:30 0.50 WHIP P WEXIT Cut 150 of coil . Pipe management for 13% CR production tubing. 12:30 - 13:00 0.50 WHIP P WEXIT Rehead pull and presure test coil connector. 13:00 - 14:00 1.00 STWHIP P WEXIT MU window milling BHA. 14:00 - 16:45 2.75 STWHIP P WEXIT RIH at minumum pump rate .66 bp @ 460 psi .13400. UPWt Printed: 3120/2006 12: 12:00 PM BP EXPLORATION O.peralionsSun1-røary.Report Page 4_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-37 P2-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/27/2006 Rig Release: 3/18/2006 Rig Number: N1 Spud Date: 8/16/1995 End: 3/18/2006 Date From - To Hours Task Code NPT Phase Description of Qperations 3/5/2006 14:00 - 16:45 2.75 STWHIP P WEXIT 50K DN WT 9.7K. Tag WS and correct to 13477'. Pinch point 5.5' below top of WS. At 2.7 bpm 2250 psi FS. 16:45 - 00:00 7.25 STWHIP P WEXIT Mill window per tirne schedule 3/6/2006 00:00 - 05:00 5.00 STWHIPI P WEXIT Continue milling window at 1 ftlhr. Normal milling parameters: 1 31OO-3400psi circ pressure, 2.5-4k# WOB. Max of 5000 psi ¡ circ p and 5.5k# WOB. No stalls. Mill-off at 13483.7'. 6.7' I window length. Drill 10' of open-hole. 05:00 - 07:45 2.75 STWHIP P WEXIT Ream and dry tag. Good clean window. 07:45 - 08:15 0.50 STWHIP P WEXIT Circulate new mud to the bit 08:15 -11:00 2.75 STWHIP P WEXIT POH laying in new mud. 11 :00 - 12:00 1.00 STWHIP P WEXIT LD window milling BHA 12:00 - 12:45 0.75 DRILL P PROD1 Rehead coil. Pull test to 35000# and pressure test to 3500 psi. 12:45 - 13:45 1.00 DRILL P PROD1 M/U 3.2 degree motor drillig assembly. 13:45 - 16:30 2.75 DRILL P PROD1 RIH wo pumping. RIH to 13200 attempt tie-in. 16:30 - 19:05 2.58 DRILL N SFAL PROD1 Attempt to tie-in.having trouble with MWD software depth. decided to tag td and relog. 19:05 - 19:40 0.58 DRILL N SFAL PROD1 Attempt tie-in to GR from 13200' to 13280'. Log at 100'/hr. Continuing BHI depth encoder problems. 19:40 - 21 :45 2.08 DRILL N SFAL PROD1 Change out BHI depth encoder system. Calibrate. 21 :45 - 22:30 0.75 DRILL P PROD1 Tie-in to GR from 13200' to 13280'. Log at 100'/hr. 22:30 - 22:45 0.25 DRILL P PROD1 Depth correct based on GR and PDC log. 22:45 - 00:00 1.25 DRILL N DFAL PROD1 Working on getting tool to orient to exit window. 3f712006 00:00 - 00:15 0.25 DRILL N DFAL PROD1 Working on getting tool to orient to exit window. 00:15 - 02:15 2.00 DRILL N DFAL PROD1 POOH for BHI orienter failure. 02:15 - 04:15 2.00 DRILL N DFAL PROD1 Laydown BHI HOT and DGS. Download tools. P/U new BHI HOT and DGS. 04:15 - 04:30 0.25 DRILL N DFAL PROD1 RIH with new BHI HOT and DGS to attempt to drill build again. 04:30 - 05:45 1.25 DRILL N DPRB PROD1 SSSV tagged at 4550 psi. Pumped up to 5000 psi, still no go. Cycle SSSV shut and open. 05:45 - 06:00 0.25 DRILL N DPRB PROD1 POH 06:00 - 08:00 2.00 DRILL N DPRB PROD1 Swap BHA 08:00 - 08:30 0.50 DRILL N DPRB PROD1 RIH 08:30 - 09:00 0.50 DRILL N DPRB PROD1 Set down on SSSV at 2109' holding 5050psi on control line. Set down 4 K. Pressure up to in increments to 1800 psi gradual bleed oft. Volume to pressure up indicated some bypass. Increase slack off wt to 10K. No Go. Tap SSSV at 40 ftlmin with 1400 psi in well. NO GO. 09:00 - 09:30 0.50 DRILL N DPRB PROD1 POH for S line unit. 09:30 - 10:00 0.50 DRILL N DPRB PROD1 LD nozzel BHA. 10:00 - 11 :25 1.42 DRILL N DPRB PROD1 Wait on S-line. 11 :25 - 11 :50 0.42 DRILL N DPRB PROD1 Held PJSM with all personnel for slickline operations. 11 :50 - 12:45 0.92 DRILL N DPRB PROD1 R/U S/Line tools & stripper head. 12:45 - 13:05 0.33 DRILL N DPRB PROD1 MIU tools & stab stripper on lubricator. 13:05 - 14:20 1.25 DRILL N DPRB PROD1 RIH with 3.825" centralizer. Zero @ rig floor. Set down @21oo WLM. 14:20 - 15:25 1.08 DRILL N DPRB PROD1 POOH & UO S/Line tools. 15:25 - 16:15 0.83 DRILL N DPRB PROD1 Pressure tbg to 18oopsi. RIH with 3.825" no-go, 3" bar, 3.625" centralizer & flapper checker. OAL - 72" & from no-go to flapper checker = 56". Tag several times @ same spot (2103' WLM). Run up & down thru valve without pulling any bind. Dump SSSV pressure & still tag @ same spot. Run up & down thru valve without pulling any bind. 16:15 - 17:20 1.08 DRILL N DPRB PROD1 POOH & pop oft & inspect flapper catcher. Observe the btm 3 Printed: 3/20/2006 12: 12:00 PM Page 5 _ BP EXPLORATION Operation mary Report Legal Well Name: P2-37 Common Well Name: P2-37 Event Name: REENTER+COMPLETE Start: 2/27/2006 Contractor Name: NORDIC CALISTA Rig Release: 3/18/2006 Rig Name: NORDIC 1 Rig Number: N1 _~~~~_J!rom -To Hours Task Code NPT Phase 3/7/2006 116:15 - 17:20 1.08! DRILL N DPRB PROD1 117:20 - 18:00 0.67 II DRI LL N DPRB PROD1 I I 118:00 - 21 :00 3.00 I DRILL N 121 :00 - 23:45 2.751 DRILL N DPRB PROD1 DPRB PROD1 23:45 - 00:00 0.25 DRILL N DPRB PROD1 3/8/2006 00:00 - 02:00 2.00 DRILL N DPRB PROD1 I I i 02:00 - 03:45 1.75 DRILL N DPRB PROD1 03:45 - 04:00 0.25 DRILL N DPRB PROD1 04:00 - 04:15 0.25 DRILL N DPRB PROD1 04:15 - 05:00 0.75 DRILL N DPRB PROD1 05:00 - 05:30 0.50 DRILL N DPRB PROD1 05:30 - 06:00 0.50 DRILL N DPRB PROD1 06:00 - 07:15 1.25 DRILL N PROD1 07:15 - 07:30 0.25 DRILL N DPRB PROD1 07:30 - 08:30 1.00 DRILL N DPRB PROD1 08:30 - 09:00 0.50 DRILL N DPRB PROD1 09:00 - 10:15 1.25 DRILL N DPRB PROD1 10:15 -11:45 1.50 DRILL N DPRB PROD1 11 :45 - 12:15 0.50 DRILL N DPRB PROD1 12:15 - 15:15 3.00 DRILL N DPRB PROD1 15:15 - 15:25 0.17 DRILL N DPRB PROD1 15:25 - 16:15 0.83 DRILL N DPRB PROD1 16:15 - 16:45 0.50 DRILL N DPRB PROD1 16:45 - 17:45 1.00 DRILL N DPRB PROD1 17:45 - 18:45 1.00 DRILL N DPRB PROD1 18:45 - 19:00 0.25 DRILL N DPRB PROD1 19:00 - 20:45 1.75 DRILL N DPRB PROD1 Spud Date: 8/16/1995 End: 3/18/2006 Description of Operations brass pins bent upwards - could be that the flapper is partially open and/or the pins bent after dumping the pressure. M/U & RIH with 3.825' no-go, 3" bar, 3.625" centralizer, 5' x 1-1/4' stem & flapper checker. From no-go to flapper end = 133'. Run up & down thru valve and pull bind. POOH. Wait on friction tool. PJSM on Sline work after crew changeout. RIH with no-go to top of SSSV. POOH, UD no go. P/U and RIH with friction tool to attempt to move the SSSV sleeve. No movement noted. Friction tool stuck in place. Attempt to circulate to aid in release. Friction tool rernained stuck at SSSV. Small movernent of about 4 feet noted periodically. No further progress. Send for wire cutter. Wait on wire cutter and oil jar system to free stuck friction tool. Run Sline cutter into hole to free from stuck friction tool. Cut sline and POOH RIH with overshot to fish sline cutter. POOH with cutter. RIH with grapple and oil jars on Sline to fish friction tool. Pull friction tool free. POOH & UD S/Line tools. Crew change. Held PJSM with all personnel for slickline operations. Wait on LIB tool. M/U & RIH 3.75" tapered LIB spaced 56' from 3.825" no go. (Zero @ no-go). Set @ SSSV & tap down 1x. POOH with LIB tool. Observe a +/-45degs indentation @ the tip of the LIB with some scratch marks on the side. Review situation with PEs & ANC & decide to run the swedge tool to attempt to shift the flapper into the recess. M/U & RIH 4-1/2' GR with swedge tool. OAL - 122.5'. (Zero @ no-go). Set @ 2097' SLM. Work tool down 4'. OAL of TRCF = 61.17". Thus will locate with 57' (ca. 5') of swedge below TRCF. POOH with swedge tool. Observe scratch marks on tapered section of tool. Also tale-tell brass pins on no-go were sheared. File up scratch marks & prep tool for repeat run. Need to work tool ca. l' deeper. RIH with wedge tool. OAL -122.5'. Same as last run. Work SSSV flapper to move into recess POOH with wedge tool. Full travel of 62' down to no-go gained resulting in clearance of 3.81'. Need to verify. Run flapper checker to verify clearance past the flapper in SSSV. Flapper checker came back clear. None of the brass pins were damaged. 3.81" clearance verified. RIH with swedge. Set @ 2102' SLM. Move down to 2107' SLM. POOH with swedge tool. Crew change. Held PJSM with all personnel for slickline operations. M/U tools for drift run. Take out all QC's. M/U 8' x 1-7/8' stem, 5' x 2-1/8' & LSS. RIH with 3.805' swedge drift thru TRCF to Printed: 3120/2006 12: 12:00 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/8/2006 I 120:45 - 21:15 121:15-22:45 22:45 - 23:15 3/9/2006 23: 15 - 00:00 00:00 - 01 :45 BP EXPLORATION Operation$S....mmary Report 0.50 DRILL N Start: Rig Release: Rig Number: Phase 2/27/2006 3/18/2006 N1 PROD1 PROD1 PROD1 PROD1 0.75 DRILL 1.75 DRILL N N DPRB PROD1 DPRB PROD1 2.50 DRILL P P2-37 P2-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Tas~od-=-lNPT 19:00 - 20:45 1.75 DRILL I N I DPRB ! I 0.50 DRILL I N I DPRB 1.50 DRILL ¡ N I DPRB , I I I I i I IDPRB I 01 :45 - 02:45 1.00 DRILL N DPRB PROD1 02:45 - 03:15 0.50 DRILL N DPRB PROD1 03:15 - 04:15 1.00 DRILL N DPRB PROD1 04:15 - 04:45 0.50 DRILL N DPRB PROD1 04:45 - 05:00 0.25 DRILL N DPRB PROD1 05:00 - 05:15 0.25 DRILL P PROD1 05:15 - 06:30 1.25 DRILL P PROD1 06:30 - 09:00 PROD1 09:00 - 10:20 1.33 DRILL N SFAL PROD1 10:20 - 10:50 0.50 DRILL P PROD1 10:50 - 11: 1 0 0.33 DRILL P PROD1 11:10-14:25 3.25 DRILL P PROD1 14:25 - 15:15 0.83 DRILL N DFAL PROD1 15:15 - 16:15 1.00 DRILL N DFAL PROD1 L P PROD1 Page 6 .. Spud Date: 8/16/1995 End: 3/18/2006 Description of Operations 2118' SLM Le. ca. 10-12' thru flapper. PUH & redrift 20x with no problems. POOH with drift tool. C/O tools to 5' x 2-5/8" stern & LSS. OAL - 95.5" & spaced 62" from 3.825" no go. M/U & RIH TRCF dimpling/lock-out tool. Set @ 2107' SLM. Pressure up well bore in stages to 1500psi to actuate collet to push down flow-tube (if not already down). Beat on dirnpler several times to dimple flow tube with 1450psi WHP. Bleed off WHP. PUH & get stuck with dimpling tool. Suspect we're hydraulically locked in due to cold/gelled-up flopro fluid in well bore & tight tolerance of O-ring & no-go tool. Surge well bore a couple of times & pull free. Will re-run dimpler 2x with smaller stem & without collet & O-rings to allow better fluid bypass. POOH with dimpling/lock-out tool. Bullhead 33bbls of warrn flopro mud downhole @ 0.5bprn/1500psL Meanwhile redress lock-out tools. Remove O-rings & collet. MU 8' x 2-1/8' stem, 3' x 1-7/8" stern, OJs & LSS. RIH with 4-1/2" TRCF lock-out tool to no-go @ 2107' SLM. Jar down for 20rnins to dimple flow-tube. Tap up. PUH & hung up @ 2030' SLM. Hit jar lick & come free. POOH with dimpling/lock-out tool. Redress & RIH with 4-1/2' TRCF lock-out tool to no-go @ 2107' SLM. Jar down for 20mins to dimple flow-tube. POOH with dimpling/lock-out tool. RID SLB S/Line. Held pre-operations resumption safety meeting with all personnel. Review well status, hazards and drilling BHA M/U procedures. M/U drilling BHA #10 with 3deg X-treme motor, BHI HOT-DGS-DPS-SBS-BCPM package & rebuilt Hughes 3-3/4' x 4-1/8" RWD2ST bicenter bit #4. Scribe tools. Initialize BHI tools & MIU injector. RIH w BHA #10 to drill build section. Passed all the way through the SSSV with BHA, then pulled BHA back above the SSSV and then proceeded down to GR tie in depth. Pass the SSSV at 25 ftImin w 5500 psi on the control line of the SSSV as precaution. No indications of sticking passing the SSSV on weight indicator. Attempt tie in to GR and function check the BHI tools/orienter. Frozen dump line off of mud manifold (connects the BHI surface actuator to the mud pit). Tie in to GR. Correct +2.5'. Function check the BHI tools/orienter. Run through window and drill build section. ROP 15 ftlhr initially - motor stalling assuming stick-slip with tools across window. ROP of 40 ftIhr average. Problems downlinking to BHI tools. Pull up into 7-5/8' casing to orient. Run back to bottom. BHI tools able to orient on bottom, but not able to hold TFO as the bit starts to drill. 3 attem ts unsuccessful. Drilling ahead u . Printed: 3/2012006 12: 12:00 PM ) STATE OF ALASKA ) RECEI ALASKA Oil AND GAS CONSERVATION COMMISSION VED REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter CasingD Change Approved Program D Repair WellO Pull TubingD Operation Shutdown 0 PluQ Perforations D Perforate New PoolO Perforate 0 Stimulate 00 WaiverD JUl 2 I 2005 Alaska Oil & Ga.~('CJmI CommP . 'Ut~rt.:.:l· '88'f n Time ~ß~~~ 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development [!] ExploratoryD Re-enter Suspended Well D 5. Permit to Drill Number: 195-1060 6. API Number 50-029-22576-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 52.10 8. Property Designation: ADL-034627 11. Present Well Condition Summary: StratigraphicO ServiceD 9. Well Name and Number: P2-37 10. Field/Pool(s): Pt Mcintyre Oil Field I Pt Mcintyre Oil Pool Total Depth measured 13815 feet true vertical 9184.2 feet Effective Depth measured 13731 feet true vertical 9135.0 feet Plugs (measured) None Junk (measured) See Attachment Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 41 121 41.0 121.0 1490 470 SURFACE 4581 10-3/4" 45.5# NT -80 40 - 4621 40.0 - 3718.7 5210 2480 PRODUCTION 13038 7-5/8" 29.7# L-80 38 - 13076 38.0 - 8746.0 6890 4790 PRODUCTION 739 7-5/8" 29.7# 13CR80 13076 - 13815 8746.0 - 9184.2 6890 4790 Perforation depth: Measured depth: 13430 - 13450,13464 - 13540,13560 -13620 True vertical depth: 8957 - 8969, 8977 - 9022, 9034 - 9070 1;;. 20 os- SCANNE.D JUL 2. ~ " TubinQ ( size, Qrade, and measured depth): 4-112" 12.6# 13Cr80 @ 35 13150 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Camco TRCF-4A SSV @ 13095 @ 2110 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl 250 240 Representative Dailv AveraQe Production or Injection Data Gas-Met Water-Bbl Casing Pressure 31 67 327 328 Tubing Pressure 744 733 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil [!] Gas D Development ŒJ Service D Signature DeWayne R. Schnorr DeWayne R. Schnorr ffi ¿t~o", ~-~J¿~ WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Petroleum Engineer Phone 564-5174 Date 7/14/05 Form 10-404 Revised 4/2004 CJ ~~ I G ! ~! " i'I,¡ L kBDMS ~Fl JUL 25 Z005 ) ) P2-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/11/05 T/I/O= 1900/170010 LOAD TUBING [PRE E-LlNE--WELL SI UPON ARRIVAL] AIL LINE SI @ MODULE. SPEARED IN WI 5 BBLS OF METH, 82 BBLS OF CRUDE, 14 BBLS OF METH DOWN TUBING. RDMO FINAL WHP'S 1750/170010 06/11/05 SHOT PROPELLANT STIMULATION GUNS FROM 13499'·13515' AND 13570'-13592'. WHP = 1550 FOR ENTIRE JOB. SSSV WAS CLOSED ON ARRIVAL, DISCOVERED BY LIGHTLY TAGGING WHILE RIH ON FIRST RUN. ABLE TO EQUALIZE AND OPEN VALVE TO CONTINUE JOB. FLUID LEVEL SHOT AFTER OPENING SSSV AND TOOL AT TD. FLUID AND GAS MIX AT SURFACE INDICATED ENOUGH FLUID AT TD TO CONTINUE JOB. USED GRICCL TO CORRELATE TO SLB CBT LOG DATED 9-11-95. GR COUNTS WERE HIGH DUE TO SCALE. LINER AT TD READING 1200-1500 GAPI'S. FLUIDS PUMPED BBLS 19 METHANOL WATER 82 CRUDE 101 TOTAL Page 1 ~) TREE = COOPffi W8..LHEAD = FMC 'A'CfüA:fÖR'·;;;·'·"....·..·...."ÊÌA·KEFfc· 'kB.ELE\7··;;;" ..... '51.5' 'ì3"F:"""Ë[ËV""; ..·.....·..,"w·,w.w."',..,,·,,·"",·,...,·,w~ ï{öp ';'''' 1106' ... ..."".................,........."...............""""'.........".......".................,..,.,.,....,...........................'" ~~" An.2.~.~.,.,""^"'~~~^'~.~^~~ Datum MD = 13254' Datum TVD = 8800' SS 10-3/4" CSG, 45.5#, NT-80, D = 9.953" 1-1 4621' r-J Minimum ID = 3.725" @ 13129' OTIS XN NIPPLE 7-5/8" CSG, 29.7#, L-80, 10 = 6.875" 1-1 13076' 1 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, D = 3.958" 1-1 13150' 1 ÆRFORA TON SUMMARY REF LOG: SWS CDR/GR ON 08/29/95 ANGLE AT TOP ÆRF: 53 @ 13430' Note: Refer to Production DB for historical perf data SIZE SFf' INTERVAL Opn/Sqz DATE 2-7/8" 6 13430-13450 0 03/17/04 3-3/8" 6 13464 - 13540 0 09/12/95 2-7/8" 6 13470-13490 0 03/17/04 2-7/8" 6 13500-13510 0 03/17/04 2-7/8" 6 13510-13530 0 03/17/04 3-3/8" 6 13560 - 13620 0 09/12/95 1 PBTD H 13731' 1 7-5/8" CSG, 29.7#, NT-13-CR-80S, D = 6.875" H 13815' DA. TE REV BY CO rvTv1 ENTS 09/03/95 ORIGINAL COM PLEfION 09/16/01 RN'KAK CORRECllONS 03/17/04 MOC/1LP AOO ÆRFS P2-37 e l " I I :8: ð" I I / ., -.. ~ DATE REV BY COMrvENTS ) SAFETY NOTES: 4-1/2" CHROMETBG & 7-518" CHROMECSG 2110' H 4-1/2" CAMCOTRCF-4A lRSSSV, 10= 3.812" 1 ~ GAS LIFT MANDRB..S ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 5096 4004 53 KMBG BK 2 7637 5506 53 KMBG BK 3 8957 6298 55 KMBG BK 4 9994 6903 53 KMBG BK 5 10826 7393 54 KMBG BK 6 11 661 7889 54 KMBG BK 7 13018 8712 53 KMBG BK ,- 13084' 1-1 4-1/2" OTIS X NIP, 10 = 3.813" 1 13095' 1-1 7 -5/8" X 4-1/2" BAKER 5-B PA Q<ER 1 I 13129' 1-1 4-1/2" OTIS XN NP, 10 = 3.725" 1 13150' 1-1 4-4/5" TIJBING TAIL, WLEG 1 13154' 1-1 ELMO TT LOGGED 09/11/95 1 13650' 1- 3.7" BROACH, PARTED AT SUO<ER ROD CONNECTON 1 13730' H HA rvTv1ER FUSHED TO BOTTOM OF HOLE I FDINT MCINTYRE UNIT WELL: P2-37 PERMT I\b: 1951060 APII\b: 50-029-22576-00 SEC 14, T12N, R14E, 4643.28' FEL & 2480.42' FNL BP Exploration (Alaska) ) ) /C¡5 - it!J(¡; ,"'ñ' tt;7~!ð" ~ ¡~ ~~~~:U, (l " / \ ¡ [, } ...., (, ,,\ \ r. f 'I I l :1".:,)) i r . '" tL :~~' w.J¿1 \\ II t~ ¡,iJlJ'i~,1) 'r6: : t:~f I n¡1 ¿/r:;1,fi1,,~ ~' OJ,' I r"1J~/{,.' fÆ18: I f'" II' ."," lj'I\\~ I , , , !ti'l[ ,u"'lL'¡I! rl,' í r : ' ¡ ", '\ '- ¡ ~ ¡V: I ;.' ,I i.¡-n\run))U' , " ; ,'*-I!: u·~ :',''1;:- FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 SCANNE~) l\PH 1. 4 20D~) Re: Prudhoe Bay P2-37 Sundry Number: 305-079 Dear Ms. Endacott: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. /S~cere~ /:~ ,'/ //;/ i ,71-;___".,../ ~ I¡~"::;:> ./ .'- Daniel T. Seamount, Jr. Commissioner DATED this 5" day of April, 2005 Enc!. 1. Type of Request:, B Abandon;' 0 Repair Well 0 Plug Perforations 0 Stimulate o Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver o Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well \r¡~/t· 4l4-/2..ðÜ$ ) STATE OF ALASKA ) D,S 1-/i-/S' ALASKA OIL AND GAS CONSERVATION COMMISSION CIlJ- 4- c; ,"s- APPLICATION FOR SUNDRY APPROQiCEIVED 20 AAC 25.280 APR - 1 2005 Alaska ~I<i,ij¡as Cons. l,;ommissÎon o TirAø~ 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current We~Class: a Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 195.;106 / 6. API Number: / 50- 029-22576-00-00 99519-6612 52.1' 9. Well Name and Number: PBU P2-37 /' 8. Property Designation: 11. Total Depth MD (ft): 13815 Casing Structural Conductor Surface Intermediate Production Liner 10. Field / Pool(s): Prudhoe Bay Field / Point Mcintyre Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): J Effective Depth TVD (ft): Plugs (measured): 9184 13731 9135 None Length Size MD TVD Burst Junk (measured): 13650 Collapse ADL 034627 80' 45811 20" 10-3/4" 80' 4621' 80' 3719' 1530 5210 520 2480 13772' 7-5/8" 13810' 9181' 6890 4790 Perforation Depth MD (ft): Perforation Depth TVD (ft): 13430' - 13620' 8957' - 9070' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker 'S-B' packer; 4-1/2" Camco 'TRCF-4A' SSSV Tubing Size: 4-1/2", 12.6# Tubing Grade: 13Cr Packers and SSSV MD (ft): 13095' 2110' Tubing MD (ft): 13151' 12. Attachments: a Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: D Exploratory a Development D Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mary Endacott Title CT Drilling Engineer -411 f" 71- Signature' ;/ ( I(~r ~þtlll (tlf· Co:;I~:~on Use5~~:BB April 10, 2005 Date: 15. Well Status after proposed work: DOil DGas DWAG DGINJ / D Plugged DWINJ a Abandoned D WDSPL Contact Mary Endacott, 564-4388 Date ~/II 06 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 3D.!:J--(;J.. 79 D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other: A1) ¡7r-o lfe J ç, r ""'- 10 · 40 I H'1~"€d £0 { (,.t· dQ þ¿\-(~ lÑLf l' P 2~ ~71r-. SC,ANNEJ') APR 1 4-~OD:' to - 40' . ~ DMS BFL APR 0 6 1005 0 R \ G \ N A L COMMISSIONER APPROVED BY THE COMMISSION Date éfl-? /5 Submit In Duplicate Approved By: Form 10-403 ) ) 0:>:> To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: M.S. Endacott CTD Engineer Date: March 31, 2005 Re: P&A operations for well P2-37 A as part of the CTD sidetrack Well P2-37 is scheduled for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or around 4/20/05. The sidetrack, P2-37A, will exit-emtt1fthe existing 7-5/8" casing off a whipstock and target a cross cut of the Kuparuk. The existing perforations will be isolated by cement below the whipstock:1'he following describes work planned for the P&A and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary 1) S - dummy GLMs 2) S - Caliper tubing to 13500' 3) S - Dummy whipstock drift to 13500' 4) 0 - MIT-IA, MIT-OA, PPPO;:-T, IC 5) E - Set whipstock at 13472' (Y) 6) C - P&A well past whipstock -\7JÆ>bl of 15.8 ppg cmt The pre CTD work is slated to begin on 4/10/05. /?lÎ(t~(/lf;t(ltlf.O« Mary ~nd oU CTD Dril ng Engineer 564-4388 CC: Well File Sondra Stewmanrrerrie Hubble .. TREE=... WELLHEAD = ",,,,,,. .......,..... '" .."....,......,. ACTUATOR = ",,,,.,,.,,t:',,,,,,,,,, KB. ELEV = BF. ELEV = 'K'ÒÞ';'" , ... MïixÅngïe';" .... ·Datum'MO·;···· Datum lVD = COOPER FMC BAKER C 51.5' ) 1106' 55 @ 9104' 13254' 8800' SS P2-37 e 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 1-1 4621' ~ Minimum ID = 3.725" @ 13129' OTIS XN NIPPLE 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 1-1 13076' 1 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 1-1 13150' 1 ÆRFORA TION SUMMARY REF LOG: SWS CDRlGR ON 08/29/95 ANGLE AT TOP ÆRF: 53 @ 13430' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 13430 - 13450 0 03/17/04 3-3/8" 6 13464 - 13540 0 09/12/95 2-7/8" 6 13470 - 13490 0 03/17/04 2-7/8" 6 13500 - 13510 0 03/17/04 2-7/8" 6 13510 - 13530 0 03/17/04 3-3/8" 6 13560 - 13620 0 09/12/95 I PBTD 1-1 13731' I 7-5/8" CSG, 29.7#, NT-13-CR-80S, ID = 6.875" 1-1 13815' DA TE REV BY COMMENTS 09/03/95 ORIGINAL COM PLETION 09/16/01 RNtKAK CORRECTIONS 03/17/04 MDCITLP ADD PERFS L \ I I z ~ I I ., -.. 1 . ~ DA TE REV BY COMMENTS ) SAFETY NOTES: 4-1/2" CHROME TBG & 7-5/S" CHROME CSG /' 2110' 1-1 4-1/2" CAMCO TRCF-4A TRSSSV, ID = 3.812" 1 ~ GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1 5096 4004 53 KMBG BK 2 7637 5506 53 KMBG BK 3 8957 6298 55 KMBG BK 4 9994 6903 53 KMBG BK 5 10826 7393 54 KMBG BK 6 11661 7889 54 KMBG BK 7 13018 8712 53 KMBG BK / 13084' 1-1 4-1/2" OTIS X NIP, ID = 3.813" 1 13095' 1-1 7-5/8" X 4-1/2" BAKER SoB PACKER 1 I 13129' 1-1 4-1/2" OTIS XN NIP, ID = 3.725" 1 13150' 1-1 4-4/5" TUBING TAIL, WLEG 1 13154' 1-1 ELMD TT LOGGED 09/11/95 I I I I 13650' 1- 3.7" BROACH, PARTED AT SUCKER ROD CONNECTION I 13730' 1-1 HAMMER PUSHED TO BOTTOM OF HOLE 1 POINT MCINTYRE UNrT WELL: P2-37 ÆRMrT No: 1951060 API No: 50-029-22576-00 SEC 14, T12N, R14E, 4643.28' FEL & 2480.42' FNL BP Exploration (Alaska) 0., COOÆR FMC BAKER C 51.5' ) TREE = WELLHEAD = ACTUNTOR = KB. B..EV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TV 0 = 1106' 55 @ 9104' 13254' 8800' SS 10-314" CSG, 45.5#, NT-80, 10 = 9.953" I., 4621' ~ Minimum ID = 3.725" @ 13129' OTIS XN NIPPLE (milled to 3.8") 7-5/8" CSG, 29.7#, L-80, 10 = 6.875" I., 13076' 1 Top of Cement 13120' TOPOF 3-1/2" 13cr80 LNR - 13120' 13.5" XN Nip 2.75" Iq-f 13150' P2-37A Proposed CTD Sidetrack e L " I I :8: :g I~. 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" I., 13150' 1 / /" PERFORA TION SUMMARY REF LOG: SWS CDRlGR ON 08/29/95 ANGLE AT TOP ÆRF: 53 @ 13430' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 13430 -'13450 isolated proposed 3-3/8" 6 13464 - 13540 isolated proposed 2-7/8" 6 13470 - 13490 isolated proposed 2-7/8" 6 13500 - 13510 isolated proposed 2-7/8" 6 13510 - 13530 isolated proposed 3-3/8" 6 13560 - 13620 isolated proposed I PBTD 1-1 13731' 17-5/8" CSG, 29.7#, NT-13-CR-80S, 10 = 6.875" I., 13815' DATE 09/03/95 09/16/01 03/17104 03/31/05 REV BY COMMENTS ORIGINAL COM PLETION RN/KA K CORRECTIONS MDC/TLP ADD PERFS MSE PROPOSED CTD SIDETRACK "" DATE REV BY COMMENTS ) SAFETY NOTES: 4-1/2" CHROME TBG & 7-5/8" CHROME CSG 2110' I., 4-1/2" CAMCO TRCF-4A TRSSSV, 10 = 3.812" 1 ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 5096 4004 53 KMBG BK 2 7637 5506 53 KMBG BK 3 8957 6298 55 KMBG BK 4 9994 6903 53 KMBG BK 5 10826 7393 54 KMBG BK 6 11661 7889 54 KMBG BK 7 13018 8712 53 KMBG BK ~ 13084' I., 4-1/2" OTIS X NIP, 10 = 3.813" 1 13095' I., 7-5/8" X 4-1/2" BAKER SoB PACKER 1 I 13129' l-i 4-1/2" OTIS XN NIP, 10 = 3.725" 1 (milled to 3.8") 13150' I., 4-4/5" TUBING TAIL, WLEG 1 13154' I., ELMO IT LOGGED 09/11/95 13500' 1"3-1/2 x 2-7/8 X-over ! r-. r-. I) l 3-1/2" X 2-7/8" 13Cr80 cmt'ed and parted I., 14450' I I 13472' l-i rv1echanical Whipstock 1 I 13650' 1- 3.7" BROACH, PARTED AT SUCKER ROD CONNECTION I 13730' 1--1 HAMMER PUSHED TO BOlTOM OF HOLE 1 POINT MClNTY RE UNIT WELL: P2-37 A ÆRMIT No: API No: 50-029-22576-01 SEC 14, T12N, R14E. 4643.28' FEL & 2480.42' FNL BP Exploration (Alaska) " r'\ r'\ " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter CasingD . Change Approved Program D 2. Operator Suspend 0 RepairWeliD Pull TubingD Operation ShutdownD Plug PerforationsD Perforate New Pool 0 4. Current Well Class: Perforate ŒI WaiverD Stimulate D Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 195-1060 OtherD Name: BP Exploration (Alaska), Inc. 52.10 8. Property Designation: ADL-o34627 11. Present Well Condition Summary: Development ŒI Stratigraphic 0 9. Well Name and Number: P2-37 10. Field/Pool(s): Pt Mcintyre Oil Field / Pt Mcintyre Oil Pool ExploratoryD ServiceD 6. API Number 50-029-22576-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 13815 feet true vertical 9184.2 feet Plugs (measured) Junk (measured) None Effective Depth measured 13731 feet 9135.0 feet 13730,13685,13640 true vertical Casing Conductor Production Production Surface Length Size MD TVD 80 20" 91.5# H-40 41 121 41.0 - 121.0 13038 7-5/8" 29.7# L-80 38 - 13076 38.0 - 8746.0 734 7-5/8" 29.7# 13CR80 13076 - 13810 8746.0 - 9181.2 4581 10-3/4" 45.5# NT-80 40 - 4621 40.0 - 3718.7 Burst 1490 6890 6890 5210 Collapse 470 4790 4790 2480 Perforation decth: Measured depth: 13430 -13450,13464 -13470,13470 -13490,13490 -13500, 13500 - 13510, 13510 -13530,13530 -13540,13560 -13620 True vertical depth: 8956.71 - 8968.71,8977.09 - 8980.68,8980.68 - 8992.64,8992.64 - 8998.61,8998.61 - 9004.58,9004.58 - 9016.49 9016.49 - 9022.44,9034.32 - 9069.82 RECE IVED Tubing (size. grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 35 13151 APR - 9 2004 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Hydro Set Packer 4-1/2" Camco TRCF-4A SSV @ @ 13095 2110 Alaska Oil & ~as Cons. Cbnnnission Anchorage 13 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Recresentative Dailv Average Production or Injection Data Gas-Me! Water-Bbl Casing Pressure 0.3 559 220 Prior to well operation: Subsequent to operation: Oil-Bbl 361 849 0 3827 875 Tubing Pressure 795 728 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilŒl GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Daily Report of Well Operations . ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ,11ð~ Signature Phone 564-4657 Date 4/6/04 RBDMS BF L 1'1121,"" Form 10-404 Revised 12/2003 -. ~ ~ P2-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/10104 CTU #5, MILL SCALE; STANDBY FOR ASRC TEST SEP RIG UP. PT SURFACE LINES. RIH W/2 7/8" WFD PDM MOTOR & 3.70" 3 BLADE JUNK MILL. POSSIBLE INDICATION OF RESTRICTION IN TUBING AT 12560' CTMD. DEFINITE RESTRICTION STARTING AT 12920' CTMD. MILLED HARD SCALE FROM13019' CTMD TO END OF TAILPIPE. BACK- REAMED. PUMPED 5 BBL FLOPRO SWEEP. POOH WITH MILL. 03/11/04 CTU #5, MILUUR SCALE; POOH WITH MILL. MILL IN GOOD SHAPE. MU AND RIH WITH 2-7/8" REEVES UNDERREAMER WI 6.75" BLADES. UNDERREAM FROM 13140' CTMD (END OF TAIL) TO 13,625' CTMD W/FLO-PRO SWEEPS. BACK REAM TO TAIL SEVERAL TIMES. DROP BALL & OPEN CIRC SUB JET OUT OF HOLE AT 60%. ASRC TO FLOW WELL BORE VOLUME SLK WATER TO TANKS THEN TURN WELL OVER TO FLOW TO SYSTEM. --JOB COMPLETE-- NOTE: HARD SCALE ENCOUNTERED FROM TBG TAIL TO TOP OF PERFS. DIDN'T SEE MUCH MOTOR WORK THROUGH PERFS. 03/17/04 PERFORATED 70' IN 3 INTERVALS WITH 27/8" HSD GUNS, 6 SPF. TAGGED TD @ 13565', COULD NOT GET DEEP ENOUGH TO SHOOT BOTTOM INTERVAL FROM 13570'- 13590'. PERF'D FROM 13430-13450, 13470-13490, 13500-13510, 13510-13530 FLUIDS PUMPED BBLS 123 65 2300 2488 60/40 Methonal Flo-Pro 1% Ex SK KCL Water TOTAL Page 1 ., . ~ TREE = W8..LHEAD = ACTU<\ TOR = KB. ELEV = BF. ELEV = KOP = --- Max Angle = Datum MD = Datum TVD = COOPER FtvC BAKERC 51]' 1106' 55~9~O4' 13254' 88()()'SS 10-3/4" CSG, 45.5#, NT-SO, Ð = 9.953" H 4621' Minimum ID = 3.725" @ 13129' I OTIS XN NIPPLE P2-37 . - r-J L - 7-518" CSG, 29.7#, L-SO. ID = 6.875" H 13076' ~ 14-1/2" TBG. 12.6#, 13-CR, .0152 bpi, Ð = 3.958" H 13150' I ÆRFORA TON SUMMARY REF LOG: SWS CDRlGR ON 08129195 ANGLE AT TOP ÆRF: 53 @ 13430' Note: Refer to Production DB for historieal perf data SIZE SA" INTERVAL Opn/Sqz DATE 2-7/8" 6 13430-13450 0 03/17/04 3-3/8" 6 13464-13540 0 09/12/95 2-7/8" 6 13470-13490 0 03/17/04 2-7/8" 6 13500-13510 0 03/17/04 2-7/8" 6 13510-13530 0 03/17/04 3-3/8" 6 13560 - 13620 0 09/12/95 I PBTD H 13731' I 7-5/5' CSG. 29.7#, NT-13-CR-80S. Ð = 6.875" H 1381 fI [}II. TE RBI BY COMMENTS 09103/95 ORIGINAL COM PLEI'ION 0911611)1 RN'KAK CORRECllONS 03117104 MDCffiP ADD ÆRFS :8: :& / -., -.. ~ DATE REV BY COMMENTS 2110' ~ ST MD 1 5096 2 7637 3 8957 4 9994 5 10826 6 11661 7 13018 I' r'\ SAFETY NOTES: 4-1/2" CHROMETBG & 7-5/8" CHROMECSG H 4-lIZ' CAMCOTRCF-4A TRSSSV, ID= 3.812" I GA S LIFT MANDR8..S TVD DBI TYÆ VLV LATCH PORT [}II.TE 4004 53 KMBG BK 5506 53 KMBG BK 6298 55 KMBG BK 6903 53 KMBG BK 7393 54 KMBG BK 7889 54 KMBG BK 8712 53 KMBG BK 13084' H 4-1/2" OTIS X NIP, ID =3.813" I I 13095' H 7-5I8"X4-1/Z'BAKERS-BPAQ<ER I I 13129' H 4-1/2"OTISXNNP,ID=3.725" I 13150' H 4-415" lUBINGTAIL, WLEG I I 13154' H ELMDlT LOGGED09/11/95 I 13650 H 3.7"BROACH.PARTBJAT ' I SUCKER RODCONNECTON I 13730' H HAMMERRJSHEDTOBOTTOMOFHOLE FOINT tvClNrYRE UNIT WELL: P2-37 PffiMT /'b: 1951060 API /'b: 50-029-22576-00 SEC 14, T12N. R14E, 4643.28' FEL & 2480.42' FNL BP Exploration (Alas ka) " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .:. REPORT OF SUNDRY WELL OPERATIONS 1. operations performed: Operation shutdown_ Stimulate _X Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 52.1 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Point Mclntyre Unit 4. Location of well at surface 8. Well number 287' FNL, 3937' FEL, Sec. 14, T12N, R14E, UM (asp's 681585, 5998297) P2-37 At top of productive interval 9. Permit number / approval number 2419' FNL, 116' FEL, Sec. 13, T12N, R14E, UM (asp's 690737, 599637) 195-106 At effective depth 10. APl number 50-029-22576 At total depth 11. Field / Pool 2482' FNL, 4644' FEL, Sec. 18, T12N, R14E, UM (asp's 691017, 5996336) Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured 13815 feet Plugs (measured) true vertical 9184 feet Effective depth: measured 13518 feet Junk (measured) true vertical 9009 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 20" 250 Sx AS 80' 80' Surface 4569' 10-3/4" 113o Sx PFE & 375 Sx Class G 4621' 371 9' Production 13758' 7-5/8" 485 Sx C~ass G 13810' 9181' RECE Perforation depth: measured 13464'- 13540'; 13560'- 13620'. ~V~------i,_.,~' true vertica18926'-8971'; 8983'-9018'. MAY 2, 9Z00! Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR Tbg @ 13151' MD. Alaska 0il & Gas Cons. Commis.~ on Anchorage Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" Baker S-B Packer @ 13095' MD. 4-1/2" Camco TRCF-4A TRSSSV @ 2110' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 465 528 934 775 Subsequent to operation 704 783 1501 787 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I her%c.~.~oregoing is true and correct to the best of my knowledge. Signed~;~ ~~ Title: Point Mac Surveillance Engineer Date May21,2001 Gordon Kidd Prepared by Paul Rauf 564-5799 .,~ Form 10-404 Rev 06/15/88 · Or, iGiflAL SUBMIT IN DUPLICATE P2-37 DESCRIPTION OF WORK COMPLETED ACID STIMULATION TREATMENT Date Event Summary 3/25/2001: 4/24/2001: 4/27/2001: 4/28/2001: 5/01/2001: RIH &tagged PBTD @ 13289' ELM. TIFL passed. Performed a CT Acid Wash Stimulation as follows: MIRU CTU. PT'd equip. RIH w/CT & jetted scale w/2% KCL Double Slick Water to 13450' MD. Jetted scale to 13570'. SI GL to bleed annulus. Pumped 22 bbls of 7.5% HCl across the open perforation intervals located f/: 13464' - 13540' MD (Kuparuk Zone) Reference Log: SWS CDR/GR 8/29/1995. 13560' - 13620' MD (Kuparuk Zone) Let soak for 1/2 hr. Jetted an additional 23 bbls of 7.5% HCl across the above mentioned perforation intervals. POOH while pumping Crude (135 bbls). RD CTU. RIH & tagged PBTD @ 13518'. Attempted Production Profile. Placed well BOL & performed a welltest. Page 1 ~ $ BEEN OR BEF ORE c :i.D~,,ieaMII,M .~OC STATE OF ALASKA ALASF .)IL AND GAS CONSERVATION CON..,. ISSION REPORT OF SUNDRY WELL OPERATIONS ;, · ... , .. ~,~ .':,; , 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate ...... :'.. [] Pull Tubing [] Alter Casing [] Repair Well [] Other Install Straddle Packer A~i'~/. 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 70.88' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1215' SNL, 802' WEL, SEC. 09, TllN, R13E J-20A At top of productive interval 9. Permit Number / Approval No. 196-106 300-026 203' SNL, 5226' EWL, SEC. 15, TllN, R13E 10. APl Number At effective depth 50- 029-21716-01 4367' SNL, 914' EWL, SEC. 11, TllN, R13E 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 4277' SNL, 922' EWL, SEC. 11, T11N, R13E Pool .............. 12. Present well condition summary Total depth: measured 14140 feet Plugs (measured) true vertical 8989 feet j~) .~ t ~; i i~,,~J/.~ ,I Effective depth: measured 14053 feet Junk (measured) ! · true vertical 8990 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" 8 cu yds Concrete 110' 110' Surface 2978' 13-3/8" 4127 cu ft Permafrost 2978' 2746' Intermediate 11150' 9-5/8" 2371 cu ft Class 'G' 11150' 8381' Production Liner 417' 7" 438 cu ft Class 'G' 10887' - 11304' 8197' - 8487' 3342' 4-1/2" 473 cu ft Class 'G' 10798' - 14140' 8136' - 8989' Straddle Packer Assembly 266' 2-7/8" N/A 13309' - 13575' 8977' - 8990' Perforation depth: measured 12630'- 14040' (seven intervals); Straddled Isolation: 13410'- 13510' true vedical 8999' - 8990' (seven intervals); Straddled Isolation: 8982' - 8988' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10811' Packers and SSSV (type and measured depth) 4-1/2" HES 'HXO' SSSV Landing Nipple at 2200'; 9-5/8" TIW 'HB-BP-T' packer at 10754'; 4-1/2" FA Production Packers at 13309' and 13575' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status oi Well classiiications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terde Hubble Title CT Drilling Engineer Date · .. : ;: Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Well: J-20A Field: Prudhoe Bay APl: 50-029-21716-01 Permit: 196-106 Accept: Spud' Release: CTD Unit: .' ;. .. . d_. - 03/06/00 N/A : '/'~;'V ';' 03/08/00' '" ¢~;;:.~¢i;' -'" ':,-:, '~.=' .. Nordic ¢1 03/07/00 1 MIRU. Kill well w/320 bbls SW. Accept rig 11:30 hrs 3/6/00. NU and pressure test BOPE. MU drift BHA (3.70" OD x 6' nozzle). RIH circulating. Well on vacuum. RIH to PBTD at 14,053'. Correct depth and flag pipe. POOH. MU lower straddle packer (Baker FA) and RIH. 03/08/00 2 RIH with lower straddle packer (Baker 4 Y2" FA). Position packer on depth, drop ball, and set packer with top at 13,575'. POOH. PU anchor, PBR, 8 jts 2-7/8" 6.5# L-80 8rd EUE straddle pipe, upper 4 Y2" FA packer. RIH. Sting into lower packer with seal assembly. Confirm latch up. Pumped ball onto seat. Set upper FA packer and shear off. Top of upper 4 Y2" FA Packer at 13,309 ft. POOH with Baker setting tool. Lay out Baker tools. RIH with nozzle and freeze protect 4 F2" tubing with MEOH to 2000 ft. POOH. Close swab valve. Blow down CT with N2. Bleed down N2 pressure in CT. Clean rig pits. Move green tank. Jack up rig. Move off well. N/U tree cap and pressure test with 4000 psi. Well secured. Released rig at 04:30 hrs, 03/08/00. PEF?.HIT DA'TA T DATA .... PLUS 95 ~ i 06 C t2.-, T ? G R 95 -~- i 08 (; ,r.) N 95 ...... i06 ,::DR · '35~ 108 F'ERF 9!5- 'i 06 6891 i0 .... 407 W a s t h e Al'e we'i'l We-'l'i 'is C OH H E N T S A n a 1 y s 'i s & d e rs c r" 'i p I:: 'i' o n r" e ,,u e 'i' v ::.~ d ? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] (~As [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 95-106 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22576 4. Location of well at surface 9. Unit or Lease Name 287SNL, 1342'EWL, SEC. 14, T12N, R14E ~'~ii:-i';i'::~:-~;;':~i : At Top Producing Interval;i ~~ 2419'SNL, 116'WEL, SEC. 13, T12N, R'4E ; ~-~_: i! ::'~~~': 11. Field and PoolP2'37 ' ' - Point Mclntyre 24~' SNL, 163' EWL, SEC. l& T12N, R~E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 52.1' ADL 034627 12. Date Spudded 13. Date T.D. Reach~ 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore ~16. No. of Completions 08/16/95 08/28/95 9/1~95[ N/A feet MSL'1 One :17. Total Depth (MD+~D) 18. Plug Back Depth (MD+~D) 19. Directional Su~ey [20. Depth where SSSV set [21. Thickness of Permafrost 13815'MD/9184'~D 13731'MD/9135'TVD ~ B ~ DI 2110 feet MD I 1800'¢~prox.) I 22. Type Electric or Other Logs Run G~NEU/DEN 23. CASING, MNER ~D CEME~I~ ~D S~NG DE~ MD CASING SIZE ~. PER ~. G~ TOP ~ ~ SI~ C~E~NG RE~D ~OU~ PULED 20" 94¢ H-40 Sudace 80' 30" 250 sx Arcticset 10-3/4" 45.5¢ NT8OLHE 40' 4621' 13-1/2" 1130 sx PF 'E', 375 sx 'G' 7-5/8" 29. 7¢ USS95 38' 13076' 9-7/8" 7-5/8" 29. 7¢ NT13CRSO 13076' 13810' 9-7/8" 485 sx Class 'G' 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. ~BING RE,RD inte~al, size and number) SIZE DE~ S~(MD) PACKER S~ Gun Diameter 3-3/8" 6 spf 4-1/2" 13151' 13095' MD ~ 13464513540' 892658971` 13560513620' 898359018, 26. ACID, F~URE, CEME~ SQUE~, ~C. DEPTH I~ERVAL (MD) ~OU~ & KIND OF MATERIAL USED Freeze Protect w/260 bbls diesel 27. PRODUC~ ~ Date First Production Method of Operation (FIo~ng, gas lift, etc.) 9/14/95 Flowing Date of Test Hours Tested 3RODU~ ~R OIL-BBL GAS-MCF WATER-BBL C~S~ IGAS-OIL RATIO ~ PERIOD ~ I Flow Tubing Casing Pressure 3ALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR ~TE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Kalubik 13385' 8878' Kuparuk River 13462' 8924' 31. LIST OF A'I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ...... ~ Title Senior Ddlling Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval repealed in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 !AAI SHARED SERVICE WELL: POOL 7 8Z-%7 BOROUGH: NORTH SLOPE UNIT: POINT MClNTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS' PAGE: 1 ACCEPT: 08/16/95 12:01 SPUD: RELEASE: 09/03/95 11:59 OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 08/16/95 ( 1) MU BHA #1 TD: 120'( 0) 08/17/95 ( 2) TD: 1880' (1760) 08/18/95 (3) TD: 4260'(2380) 08/19/95 ( 4) TD: 4630'( 370) 08/20/95 (5) TD: 4630' ( 0) 08/21/95 ( 6) TD: 6000' (1370) MW: 0.0 VIS: 0 MOVE RIG T/SITE. ACCEPT @ 00:01 ON 8/16/95. RU T/TEST DIVERTER. WITNESSING WAIVED BY LOU GRIMALDI W/AOGCC. MIX SPUD MUD & MU BHA #1 DRILLING MW: 0.0 VIS: 0 MU BHA #1. DRILL T/1880. DRILLING MW: 0.0 VIS: 0 DRILL T/3240. CBU. 175% HOLE VOL. POOH T/863 & RIH T/3240. DRILL T/4260. CBU @ 4624' MW: 0.0 VIS: 0 BHA RUN #1. DRILLED T/4630'. DRILL & SURVEY 4260' T/4630' REACHED PLANNED END OF RUN - SECTION/WELL TD. CBU @ 4630', 175% HOLE VOLUME. POOH T/1077'. AT TOP OF CHECK TRIP INTERVAL. RIH T/4630'. ON BOTTOM. CBU @ 4630',170% HOLE VOLUME. POOH T/1077'. PULLED & LD BHA. RAN 10-3/4" CSG. RU CSG HANDLING EQUIP. RAN CSG T/4624'.HANGER LANDED. CBU @ 4624' RU ALL FUNCTIONS MW: 0.0 VIS: 0 RUN 10-3/4" CSG T/4624'. HANGER LANDED. MIXED & PUMPED 514 BBL SLURRY. 40 WATER, 437 BBL LEAD @ 12#, 77 BBL TAIL @ 15.8#, DROP PLUG. DISPLACED SLURRY 431 BBL. PLUG BUMPED 2000 PSI. FLUSH HYDRIL & RISER. LD LANDING JT. TOP JOB W/ 30 BBL. TYPE 'C' PERMAFROST. RD DIVERTOR. NU ALL FUNCTIONS. PREPARE TO TEST. BHA RUN #2 F/4640'T/6000'000' MW: 0.0 VIS: 0 NU & RU ALL FUNCTIONS. OK. TEST WELL CONTROL EQUIP. RU BOP STACK. OK. SURFACE EQUIP. LEAKED. HYDRIL WILL NOT TEST. RD UPPER ANNULAR. CHANGE OUT ANNULAR RUBBER. OK TO 3000 PSI. RUN BHA #2. RIH T/4536' @ FLOAT COLLAR. TEST CSG. OK TO 3000 PSI. RUN BHA #2. DRILLED CEMENT T/4640'. DRILL F/C, CEMENT, & 10' NEW HOLE. PERFORM FIT. OBTAINED LEAK OFF 15.020 PPG ENW. SERVICE BLOCK LINE. 53' DRILLING LINE SLIPPED & CUT. RUN BHA #2. DRILL & SURVEY F/4640' T/6000' : POOL 7 OPERATION: RIG : POOL 7 PAGE: 2 08/22/95 (7) TD: 8182' (2182) 08/23/95 (8) TD: 8520'( 338) 08/24/95 (9) TD:10025' (1505) 08/25/95 (10) TD:l1630' (1605) 08/26/95 (11) TD:12710' (1080) 08/27/95 (12) TD:13400' ( 690) POOH T/8000' MW: 0.0 VIS: 0 RUN BHA #2. DRILLED T/6145'. START SCHEDULED WIPER TRIP. CBU @ 6145',100% ANNULAS VOLUME. POOH T/4630'. PULLED TIGHT F/5395' T/4736 BACK REAM & PUMP OUT. PULLED CLEAN F/6145' T/5395'. AT TOP OF CHECK TRIP. RIH T/6145'. DRILLED T/8182'. CBU @ 8182',100 BBL HIGH - 40 BBL LOW VIS SWEEP. SWEPT HOLE W/ SLUG, 140% HOLE VOLUME. POOH T/8000' DRILLED T/8520' MW: 0.0 VIS: 0 RUN BHA #2. POOH T/197'. PULLED TIGHT, SWABBING PUMP/BACK REAM F/7943' T/5867'. PULLED CLEAN 5867' T/SHOE. PUMP DRY JOB @ SHOE. PULLED BHA. RUN BHA #3. SHALLOW TEST MOTOR & MWD. RIH T/4600'. PU 30 JTS 'G' PIPE. SERVICE TOP DRIVE. OK. RUN BHA #3. RIH T/8182'. WASH & REAM F/7268' T/7550' & LAST 100' TO BOTTOM. DRILLED & SURVEY F/8182' T/8520'. MW: 0.0 VIS: 0 RUN BHA #3. DRILLED T/9350'. STARTED WIPER TRIP. CBU @ 9350',100% ANNULUS VOLUME. POOH T/8120'. SHORT TRIP 13 STDS TO LAST BIT RUN, HOLE IN GOOD SHAPE. AT TOP OF CHECK TRIP INTERVAL. RIH T/9350' DRILLED T/9473'. MUD PUMPS FAILED, CIRC. REPAIR MUD PUMPS. C/O SWAB & LINER IN #1 PUMP. OK. RUN BHA #3. DRILLED T/10025' DRILLED T/11630' MW: 0..0 VIS: 0 RUN BHA #3. DRILLED T/10667'. START WIPER TRIP. CBU @ 10677',100% ANNULUS VOLUME. POOH T/9354'. 14 STD SHORT TRIP. AT TOP OF CHECK TRIP INTERVAL. RIH T/10677'. HOLE IN GOOD SHAPE. DRILLED T/11630'. DRILLED T/12710' MW: 0.0 VIS: 0 RUN BHA #3. DRILLED T/11675'. START WIPER TRIP. CBU @ 11675',150% HOLE VOLUME WITH CLEAN RETURNS. POOH T/4600' AT 10-3/4" CASING SHOE. HOLE IN GOOD SHAPE. CHANGE PUMP LINERS & SWABS. CLEANING PITS FOR KCL MUD CHANGE OVER. SERVICE TOP DRIVE. RUN BHA #3. SINGLED IN DP T/6300'. 54 JTS PU. RIH T/11674'. ON BOTTOM. CBU @ 11674'. PUMP 50 BBL LOW VISC SWEEP, 100 BBL HIGH VISC SWEEP, 1000 BBLS KCL MUD. HOLE DISPLACED WITH WATER BASED MUD, 100% DISPLACED. DRILLED T/12710'. TEST WELL CONTROL MW: 0.0 VIS: 0 RUN BHA #3. DRILLED T/13400'. HOLE TAKING FLUID ALL DAY AT ABOUT 7 BBLS/HR. HIT HARD STREAK @ 13152 MD/8790 TVD. BEFORE THIS STREAK P-RATE WAS ABOUT 110 FPH, AFTER STREAK DRILLED @ 70 FPH. DIRECTIONAL OBJECTIVE MET @ +/- 75' MD ABOVE THE TOP OF KUP. CBU @ 13400',150% HOLE VOLUME OBTAINED CLEAN RETURNS. POOH T/200'. MONITOR WELL, PULL 10 STDS WET, PUMP DRY JOB. POOH. PULLED BHA. SERICE BLOCK LINE. LINE SLIPPED & CUT. CLEAR FLOOR. TEST WELL CONTROL EQUIPMENT. : POOL 7 OPERATION: RIG : POOL 7 PAGE: 3 08/28/95 (13) TD:13760'( 360) 08/29/95 (14) TD:13815' ( 55) 08/30/95 (15) TD:13815' ( 0) 08/31/95 (16) TD:13815' ( 0) DRILLED T/13760' MW: 0.0 VIS: 0 TEST WELL COTROL EQUIP. TEST RAMS, SCR VALVES, MANUAL VALVES, TOP DRIVE VALVES, CHOKE MANIFOLD TO 250/5000 PSI. TEST HYDRIL TO 250/2500 PSI. TEST ACCUMLATOR SYSTEM. TESTS WITNESSED BY THE STATE MAN-BOBBY FOSTER. PRESSURE TEST OK-5000 PSI. RU WELL CONTROL. SET WB. EQUIPMENT WORK COMPLETE. RUN BHA #4. MU BHA #4. PU LWD TOOLS & ROTARY ASSY. LOAD LWD TOOLS & SURFACE TEST. RIH T/4500' @ 10-3/4" CSG SHOE. SERVICE TOP DRIVE. RUN BHA #4. RIH T/13308'. BENCH MARK SURVEY @ 5605'. REAM TIGHT SPOTS @ 12360',12455', 12834',12928',13308'. REAMED T/13400'. MADD PASS TO BOTTOM. ON BOTTOM. DRILLED T/13760'. POOH T/7230' MW: 0.0 VIS: 0 RUN BHA #4. DRILLED T/13815'. REACHED PLANNED END OF RUN-SECTION/WELL TD. CBU @ 13815',175% HOLE VOLUME OBTAINED CLEAN RETURNS. BACK REAMED T/12076'. SHORT TRIP 18 STDS, TIGHT. PUMP & BACK REAM ALL BUT LAST STD. DRAGGING TIGHT SPOT UP HOLE. REAMED TO 13815'. REAM TO BTM TO CLEAN HOLE. MADD PASS WHILE REAMING. ALITTLE TIGHT AFTER GETTING KUP. SOME PACKING OFF ON BTM. CBU @ 13815',200% HOLE VOLUME OBTAINED CLEAN RETURNS. POOH T/7230'. BACK REAM FIRST 3 STDS,VERY TIGHT @ 13675'. PULLED GOOD AFTER STD 3. START MADD LOGGING AT 12076'. HIT TIGHT SPOT @ 12045'. ABLE TO WORK THRU WITHOUT BACK REAMING. POOH T/12208' MW: 0.0 VIS: 0 RUN BHA #4. POOH T/200'. MADD LOGGED TO SHOE. PULLED BHA. LD STAB,DOWNLOAD CDN & CDR. LD LOGGING TOOLS & MWD. RUN BHA #5. CHANGE JETS IN BIT. RIH T/4600'. AT 10-3/4" CASING SHOE. SERVICED DRILLFLOOR/DERRICK (TOPDRIVE & DRAWWORKS). RUN BHA #5. RIH T/13412'. REAMED TO BOTTOM @ 13815'. SOME PACKING OFF. CBU @ 13815',200% HOLE VOLUME OBTAINED REQ'D FLUID PROPERTIES. RAISE MW TO 10.2 PPG, RAISE MINERAL OIL CONSENTRATION TO 5%,ADD SOLTEX 710 GPM, 120 RPM. POOH T/12810'. SHORT TRIP,PULL TIGHT,BACKREAM ALL. DRAGGING SOMETHING UP HOLE AGAIN. AT TOP OF CHECK TRIP INTERVAL. RIH T/13810'. ON BOTTOM. CBU @ 13815',180% HOLE VOLUME OBTAINED CLEAN RETURNS. RAISE MW TO 10.4 PPG. POOH T/12208'. PULL 13 STDS,PUMP DRY JOB, POOH. LITTLE TIGHT @ 12810',TOP OF SHORT TRIP. RUN CASING T/7000' MW: 0.0 VIS: 0 RUN BHA #5. POOH T/4200'. AT 10-3/4" CASING SHOE. SERVICE BLOCK LINE. LINE SLIPPED & CUT. RUN BHA #5. POOH T/171'. PULLED BHA. SERVICE TOP RAM. PULL WEAR RING, SET TEST PLUG. CHANGE TOP RAM TO 7-5/8". TEST DOORS T/2500 PSI. OK. RUN 7-5/8" OD CHROME CASING T/733'. PU FLOAT JTS,18 JTS OF CHROME & MARKER JT. LD CHROME TOOLS. PU 350 TON ELEVATORS & SLIPS. MU LEFLUER CIRCULATING HEAD. RAN CASING T/7000' CIRC CASING VOLUME @ SHOE. : POOL 7 OPERATION: RIG : POOL 7 PAGE: 4 09/01/95 ( 17) TD:13815' ( 09/02/95 (18) TD:13815' ( 09/03/95 (19) TD:13815' ( 09/04/95 (20) TD:13815 PB: 0 o) o) o) N/U STACK, C/O 7-5/8 RAMS MW: 0.0 VIS: 0 RAN CASING T/10700'. LOSING SOME RETURNS. GETTING BACK ABOUT 1/2 DISPLACEMENT. CIRC AT 10700'. RAN CASING T/13815'. STARTED GETTING STICKY AT 11230'. WORK EVERY JT IN THE HOLE, TEMPORARILY DETAINED AT 12920' AND 13000'. SPUD THE REST OF THE PIPE TO BOTTOM AT SETTING DEPTH 13815'. CIRC AT 13815'. MIXED AND PUMPED SLURRY. RELEASED TOP PLUG. DISPLACED SLURRY. PLUG BUMPED. CIP AT 23:16 HRS. RELEASED PRESSURE, FLOATS HELD. N/D DIVERTER AND BOP STACK. INSTALLED CASING HANGER AND SEAL ASSEMBLY RUNNING TOOL. INSTALL PACKOFF AND TEST. N/U BOP STACK, C/O 7-5/8 RAMS. RAN TUBING T/11040' MW: 0.0 VIS: 0 NU BOP STACK, CHANGE RAMS. RD CEMENTING HEAD AND CASING EQUIPMENT. L/D LANDING JT AND CUTT OFF JT. RU AND TEST CASING. RU HALLIBURTON WL, RUN 6" GAUGE RING T/13730'. RD THE WIRELINE EQUIPMENT. COMPLETED RUN WITH DRIFT F/0' TO 13730'. RU TO RUN 4-1/2" CHROME TUBING. RAN TUBING T/il040'. RU TO RUN SSSV, M/U SS CONTROL LINE AND TEST TO 5000 PSI. RAN TUBING TO 12150' MW: 0.0 VIS: 0 RAN TUBING T/13116', 4-1/2" OD. PICKING UP TUBING HANGER, LOST PRESSURE ON CONTROL LINE. TRIED TO PRESSURE BACK UP. CONTROL LINE IS LEAKING DOWNHOLE. L/D TUBING T/2063', PULL SSSV W/BALLED UP CONTROL LINE TO BASE OF STACK. ND BOP STACK. SPLIT STACK TO RETRIEVE LOOSE CONTROL LINE PIECES AND SS BANDS WHILE THEY CAME THROUGH PACKOFF. NU BOP STACK. RECOVERED 19 SS BANDS AND LOTS OF SMALL PCS OF CONTROL LINE. PULLED SSSV TO RIG FLOOR, STRIP BALLED UP CONTROL LINE OFF PIPE. NU STACK. R/U NEW CONTROL LINE AND HOOK UP TO SSSV, TEST LINE AND VALVE. RAN TUBING T/12150'. RELEASE RIG, 09/03/95 2400 HRS MW: 0.0 RAN TUBING T/13150'. HOOK UP CONTROL LINE TO TUBING HGR, TEST, LAND TBG, RILDS. L/D LANDING JT, R/D TBG EQUIPMENT AND CAMCO. RD BOP STACK. NU SURFACE TREE. TEST PACKOFF. TEST CONTROL LINES. XMAS TREE EQUIPMENT IN POSITION. TEST SURFACE TREE. R/U DSM LUBRICATOR AND PULL 2 WAY CK. R/U MANIFOLD, GAUGES AND SENSORS FOR CIRC AND TESTING. HOOK UP VAC TRUCK W/DIESEL TO RIG PUMP. CIRC DIESEL DOWN TUBING TO UNDER BALANCE TUBING AND FREEZE PROTECT ANNULUS. DROP BALL W/ROD TO XN NIPPLE. SET PACKER. BLEED TUBING PRESSURE. PRESSURE ANNULUS FOR PACKER AND ANNULUS TEST. BLOW DOWN LINES. R/D MANIFOLD AND CIRCULATING EQUIPMENT. SET BPV. RELEASE RIG AT 2400 HRS 09/03/95. MOVE RIG. SIGNATURE: (drilling superintendent) DATE: ~ELL HE;z.~, LOCATiO~q: L ;4 -T < ?-:, i - :' ::. 0,-00 T2.;'(E/-:j) (.'-..-2_ rA~.-. NO, 2 · ~'2-.q7 :--'t f: ft O, O0 :';:, 0 0 ~ 0,"-.:: "'"" '..'J 7 ~ '7r iu...-'- ,. 72 11,'?,? .... ' .... · --,:*':, v:., ?% 1 20?', 05 -;";'-:', .'-'-' ?'-3.= 2 2?9, '.---',5 3~.,'~,~7 ~7,? .... 1.7 ... 00.; , ~^- ...... ~"~" LATITUDE ~bllum iNULm N/-S ft deg deq ft 0,00 O,CO 0,00 0,00 -0,2! 0,24 ESB,Oi -0,05 -0,&7 0,23 29i,64 -O,0? -0,?? 0,09 67,79 0,00 DEPARTURE nY~:. *.~" "- E/-W f: ft 0,00 0,00 -0,23 0,23 -0,60 -0,72 -1.02 1,02 AZiP~TH 0,00 258,0t 258,0i 264,2! 26F,87 DLS de:/ iOOft 0,22 0,03 U,: , 0,34 AST,bA on .i *:7,3i 745,44 67,6 745~27 1,15 1,22 106~03 ?,il a,-?~ !0,06 1,5,80 5,77 10i,~8 -3,it ..... ,'..-,-,.:,'6 _F',.qo 0,37 "?'"' '" - i.-.i2 I.'''~'.,:. iuZ,'"" :'~ -. '.IL: . - 3,?3 4,0! !C,!,7~. i ,3,'_.3 8,77 9,12 1~,5.c.-' 2,06 ., l =..s, i ..A "'-' ~ F-,.0 ao 1- 7.1 _',.,,.~-: _.,~:~ ~-~ ,,~-~ ,, . 10i0,26 ii06,43- 1200,12 1295,40 87,:3 1008,25 ~q.'7 i~'' 27,06 7,3? i02,94. .=_.,¢,.o= 26,00=" ,,;;,u/"- 10i,45 !,82 39,33 8,67 i03,58 -6,I? 38,48 39,34 i02~02 1,46 oJ,91 1!,33 i65,72 -12, 75,27 t9.~: ' - ~nq.91 aA.hA '=" i02 .... -~ "~,~. 103,74 ...... * *5'a.-"' *: "-' i4.52,7¢ 4 L''T~' :':"7 !¢,:' £, ~ .--" i7.5.2,34 94,1 !377,-14 · 73~2 1554,72 7!,4 1723,68 !23,71 16,45 i02,08 -27,03 ~:~ == 1A-~ i04,74 -35,52 1~'2,0,5 19,96 104,52 -43,23 215,77 21,4'? i02,i4 ~a~,=.._~ ~.~.~ 104,00 -<n,79~=. · : ,_'U, ,"o 122,7! ..'~ 4."-.., 51.4, ..,. 151, =,,,:, 103 :_,.,=..=. 2+i4 !7,5,87 i82.,-08 i03,73 ! ,.,50 -_w.,.;,. 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A~'~.-*'.:o ~. au ?197,F 6437,33 -0,07 7292,6 6492,43 -0,18 '",* ~ ~ ,' 7~,.~5 n2 -0,06 9580,0 6659~55 -0,02 9673,6 6713,90 0,14 ?7Aq,~ ATAg.00 _r, =o ..' ._...; :_: .:,; ._ 9'762,4 6833,66. -0,72 . 10148,4 6994,2--'.:-' ~,,'?t':-' : 7049",?4 10333,0 7106,21 0,!6, ~,,,..,~"'r'~'~: ,l 7!,:.0,03 v",32' ~,r;=.,x -.-v--,~=,42 i057!6,4 -'""~' "'~' .,-.~.,',=.=-, -0,78 iOS!£.,2 7384,79 0,22 10907,0 7440,63 0,36 11100,7 !!!73,5 ...... v,__ ! ;'a?~ ~ C~g CUMAZM CHG TURN RATE dea/lOOft 53,07 -0,53 0,27 465,06 =o o= -0-71 o, flc,~:,~..~,.,~ TOOL FACE DLS DLSRT' -- ft 6eq d. eo/lOOft - .,--_.. w~t ~.-- ~ 52,93 -0,i7 -0,,ii 462,39 52,q0 -r, ,",a 1.7! 444.10 -- ~ -fi ~O - >Z.~:, v,,~ -0,>3 463,_.,=~ g9-80 u,a/ -u,~ii 46a,~0 0,9~ 0,'7-"i 1557_,,=''' O,~°_,,., O,i!' ' ' -!~66 _a ._.'. o 99,1'? ~,34 -!,66 -'[:', 0974,02 i' .3._,~O,r''~,,-' ,-. v., f:.<,q =-.a. 19 fi,~ .: 0 vo .:],... ff -..-, ..: VD 0,80 .~._,,._.:c.? i~ 13,AC, ...... 53,9A 0,24 -n,-q~.~.~ 1,22 72,4.5: 0,49. 0 -,o,~:: 159! _, ~,6,,,r 0,36 0,1i 42'.. t)i .,w ~ .,' .. ..., ,..' 'i i, c./ ....... ~ '.., o, 0,,65 - -O,DD. 9,/,2 ....,; ~,.,~ i,,-,; -0.!2 .,13 :31_:'..:';,~ .'"' "'~ · ' ...... _-.8 54,53 0,i5 -O,'J3 463,02 54,56 O?D3 0, i3 463,!5 ~-' ,59 0,03 -0,15 463,00 ?,cz ...... -0,07 -0,14. 462,~7=, 54,34 -0,i? 0,'77 463,85 -0,48 0,08 !201.37 0,45 a, ,~,/"- v,:¢~ ?z,30 i,ao,,. 0,.57 -0,39 -0,97 15,47 ~,i6 0,0~. -0,30 -1,23 .~.:~o 1,57 '~ "" 0,20 0,24 14,75 O,~''' 54,45 _n.av...~, -~,15, 462,14 54,44 -n.02,. i,'"l~ ~..,~,:,., ~'~-,-~:~ 0,i5 -1,24 ai~,02 -- ..... - U,Y! .. 0~14 -i,: .... v' 76,52 ,3,!2 0,22 ,'i '~ -'~ 1~04 -!,43 57,24 54,02 -0,-':;:5 -0,65 462,28 53,30 -0:73 -0,55 46i,73 ~':'-"* 0.,.13 -'-3, ~,e ~,_.z ~_,.-.' Dd .,t.Y ~J, ,.id: -A ~'"' ~ "-:' .. ,..:.~' ...... i8- 53~3,--' 0,20 ..... ,_:~ ... _: 54,26 O,Ag_. -~.20... 4A!. ,..s9 _,~. ~ ~ ,~. ~ . . , .~ ~ .,. 54,30 0,~/'~' !,22 ~63,88 53,52 -0,79 -i.17 462,72 -0,,5-8 !: 05 '74, ? ! O. '5-_'5.'. O, '-12 -0,56 255.S ~ ::':.,:.: n."' 0,'.:~ O, '? 3 3,71. ::_..~::, ,~_.," = 0,76 '.:., ....: _ · ~,.. -"':'.,,-.,.,.~ 4,.':.,,"':'.,, ._,,'-"" 0,47 0,.34 -!,'35 9,.37 :_':.~5,75 0,&7 0,47 53,73 0,22 1,60 ~,~, -:,nc n,.qg= __ 0,07 464,38 52,98 -i,17 0,6! 464,99 ~. ~, ~ r.~ DdtVO V*~'~ 0 ~-~ ~ n,?n -0 ~ 464,43 !,38 8,'36 82,(:5 !,i3 0,27 i,53 1i,55 i05~25 !,27 0,11 1,32 1i,34 i6,4i !,19 0,20 -I,!S ,5,AA 77,02 1,24 _ g.~ ~_.',_ _._., ~.._. 0,07 8,87 7,9,£. 0,38 1,04 ........ : ,25 O,-.f4 a,. :, i.:o,.z, ! 0,95 :i C,~. ~ V,/?' 0,2'.z' i ~:dC: v,~,, d,96, ............ ,' -0,94 !1,07 :':..n .... ,~ "~'" 0,56 . ,- ov, ',.,,.., SLl~¥~f ANAt V.q t c' *.*~..~.*** CIF,~ULA. R AEC M.,F~HOD **~******* MD TVD INC_CHG CUMIFE_CHG I_RATE ft fr deg. deg de~.'lOOft 11287,i 7&57,98 0,~ 53,48 0,,~ 11384,0 77~,53 0,21 53,69 11474,9 7/79,26 0,11 53,80 0,12 .~.¥, 0,19 11&54,0 7871,09 -0,66 53,3i AZM CHG CdMAZM CHG deg. deg TURN RATE CLOSURE TOOL FACE DLS deg/lOOft ft deg deg/lOOft DLSRT- deg/lOOft**2 1,54 465,97 1,65 -1,04 7%92 1,34 0,61 -0,86 %5," · l -0.89 -4,35 73,38 0,75 0.62 -0,18 4.M.93 -0,20 -6,79 53,00 0,~ 0,60 -I,12 463,81 -1,i8 -8,46 79,17 0,97 0,82 0.05 4~J,86 0,05 1,69 75.58 0,70 0,29 11762,3 7947,50 0,42 53,73 0,43 11857,9 80~5,96 0,i7 5~,,v 0,18 11950,5 8061.36 -t,27 52,63 -I,37 12C~5,3 81i8,92 -0,06 ,~,~.~ ~ -0+06 12140,4 8t76,72 -0,02 52,55 -0,02 0.21 464.07 0.22 -10,60 22,09 0,46 0,25 0,19 4~,26 0,20 -12,02 42,09 0.24 0,23 -0.44 463,82 -0,47 -13,23 164,72 1,42 1,27 -0,69 4~J,i4 -0,72 -13,72 96.63 0,58 0,85' 0.86 464.00 0,90 -9,42 176,58 0,72 0,15 1~35.6~3~,61. 0,00 52,,,~ 0,00 !2~0,6 82~.50 -0,17 52,38 -0,18 12426,4 8350,9? 0,00 ~,~ ~ 0.00 12519,7 8407.88 0,04 52.41 0,04 12613,8 8%55,34 -0,08 52.3~ -0,09 0,07 464,07 0,07 -15,54 94.71 0,05 0,70 -0,26 463,81 -0.27 -16.63 129,53 0,28 0,24 -0,56 4~3.25 -0,58 -17,18 90.31 0,46 0,I9 -0.27 462,98 -0,29 -17,I9 80,62 0,23 .0,25 -0.~.. 462,62 -0,38 -14,37 91,69 0,3t 0,09 12706,8 ~,~ -0,13 =~ ..... J=,20 -0,!4 0,62 463,24 0,66 -16,56 t05.48 0,54 0,25 12799,6 8579,~ -0,12 52,08 -0.i3 0,49 4.~,73 0,53 -17,04 107,74 0,44 0.1i 12871 ~ 8635.71 0,34 5=,4~ 0.37 -0.79 462,74 -1.08 -17,20 66,65 0.93 0,53 12~!,4 8695,7! 1,00 53,42 1,01 0,11 462.85 0,il -16,76 4,8! 1,01 0,08 I3M4.7 8751.14 0,23 53,65 0,25 -0j2 462.13 -0,77 -16J? 106,47 0,67 0,37 13179,5 8~07,27 0,06 ~ ~ . ,~,7~ 0,07 0,88 463,01 0,92 -15,24 85,24 0,75 0.09 !3~4.~ ,8863,45 -0,22 53,49 -0,23 -0,65 462.35 -0,69 -14,67 !13,04 0,60 0,15 1~40,6 8?03,0? -0~17 53,32 -0,26 0,!0 462.46 0,16 -!4,01 154,34 0,29 0,48 13410.1 2?44,75 -0,27 53,05 -0,39 -I.'-~ 461,24 -t,76 -12,79 105,84 !,46 1,69 13506,6 ?{<~2,47 0,33 53,38 0,34 0.78 %2,0! 0,8! -15,95 68,56 0,73 0,76 i3602.1 ?059.20 0,3? 53.77 0,40 0,08 %2.09 0,08 -9,37 8,55 0,41 0,34 o,.,~,? ¥!~n,¥o 0,39 94,1A 0,43 -O,YD %1,15 -1,04 -7,45 63,14 0,94 0,58 13730~2 9!34,49 -0,.~ ~' 54,16 -0,02 0.75 461,89. 2,03 -6,o~'~ 90,77 .,6.~ ~ 1,yi-' SURVEY F'ROJEC?;~ TO TD 13815,0 9!84.13 0,00 54.16 0.0! o,oo 461.89 -0,0! -5,'I6 7?,84 0,03 1,?0 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9770 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy Well Job # Log Description Date BL RF Sepia Disk 10/2/95 P2-37 ,._ [,/ ~ 950829 I 1 P2-37 "~ ~ ~ ' 95312 (:33E/C3:~ 950829 I SIGNED: '"" ~' "' " '" .... ~j .... ~ ............................. DATE: . ' ,1/ /..-"" · / ,/ /' /' /,,- /,' GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9734 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 9/19/95 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy Well Job # Log Description Date BL RF Sepia Disk P 2-3 7 ~,~'- I.~ / PERF RECORD 9 5 0 91 2 I 1 P2-37 /,,)"/U~ 95313 CBT 950911 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. MEMORANDUM TO: THRU: David ~ston, Chairma'n . Blair Wondzell, ~ P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE' August 27, 1995 FILE NO: A211H1CD:doc FROM: Bobby Foste r, ~'~,~_ SUBJECT: Petroleum InspectoY BOPE Test- Pool 7 ARCO - Pt. Mclntyre - 2P-37 PTD # 95-01 O6 Prudhoe Bay Field Sunday, August 27, 1995: I traVeled this date~RCO's Point Mclntyre well 2P-37 being drilled by Pool rig 7 and witnessed the weekly BOPE test. As the attached AOGCC BOPE Test Report show~,there was 1 failure. A valve down stream of the chokes leaked. The valve was greased, cycled and retested OK. The location was clean and all excess drilling equipment was properly stored and there was good access to all areas of the rig. The rig was clean and all equipment seemed tobe in good working order. Summary.: I witnessed the BOPE test on Poool rig 7 drilling ARCo's Point Mclntyre wel12P-37 - test time 2.5 hours - 1 failure. Attachment: A211H1CD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: POOL-ARTIC Operator: ARCO Well Name: POINT MclNTYRE 2-37 Casing Size: 10.750" Set @ Test: Initial Weekly Rig No. 7 PTD # Rep.: Rig Rep.: 4624' Location: Sec. X Other DATE: 8/27/95 95-0106 Rig Ph.# 659-4815 /16 LES PEAK JIM DA VIDSON 14 T. 12N R. 14E Meridian UM TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. YYES BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve N/A Test Press. P/F 300/3,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500/5, O0O P 1 500/5, OOO P 1 500/5,000 P 1 500/5, 000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F 500/5, 000 P 38 500/5, 000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: 6 @ 2200 3,050 I P 1,450 I P minutes 35 sec. minutes 22 sec. YES Remote: YES Psig. TEST RESULTS Number of Failures: '/ ,Test Time: 2.5 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Failure: A valve in the choke manifold leaked - greased, cycled and retested OK. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev, 12/94) A21 IH1CD.XLS STATE OF ALASKA : ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program X Pull tubing __ Variance__ Pedorate __ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development x 52 Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. 0. Box 196612, Anchorage, Alaska 99519-6612 Service__ Point Mclntyre 4. Location of well at surface 8. Well number 287' SNL, 1342' EWL, SEC. 14, T12N, R14E At top of productive interval 2412' SNL, 5186' EWL, SEC. 13, T12N, R14E At effective depth At total depth 2445' SNL, 50' EWL, SEC. 18, T12N, R15E feet P2-37 9. Permit number 95-106 10. APl number 50- 029-22576 11. Field/Pool Point Mclntyre 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) feet feet feet feet Size Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth AUG 1 5 995 Dit & Gas Cons. Commission '-, N~chorage 13. Attachments Description summary of proposal__ Detailed operations program X BOP sketch __ 14. Estimated date for commencing operation August 15, 1995 16. If proposal was verbally approved Oil ~ Name of approver Bob Crandall 08/11/95 Date approved Service 17. I he.~~i~ that, the foregoi correct to the best of my knowledge. -~R~OR COMMISSION USE ONLY 15. Status of well classification as: Gas Suspended__ Date Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test ~/ Location clearance Mechanical Integrity Test~ Subsequent form required lO- Original Signed By Approved by order of the Commission r~avid W. Johnston Form 10-403 Rev 06/15/88 /_7, o7' J Approval No.?~.-_/y ~_~ ¢,pproved Copy Returned Co~m}ssione/r SUBMIT IN TRIPLICATE I Well Name: P2-37 Well Plan Summary ] Type of Well (producer or injector): ] Producer Surface Location: 287' FNL, 1342' FWL, Sec. 14, T12N, R14E UM Target Location: 2412' FNL, 5186' FWL, Sec. 13, T12N, R14E UM Bottom Hole Location: 2445' FNL, 50' FWL, Sec. 18, T12N, R15E UM ]AFENumber: ] 2C0077 Estimated Start Date: ] 8/13/95 ]MD: 113763 ] I Well Design (conventional, slimhole, etc.): I Rig: ]Pool#7 Operating days to complete: ] 24 IT VD: 19146'rkb I IKBE: I52. I [ Slimhole longstring ] Objective: [ Pt. McIntyre eastern flank producer Formation Markers: Formation Tops MD TVD(BKB) Base Permafrost 1826 1787 K-15 7129 5192 West Sak 10174 7007 Minimum required MW 9.5 ppg K-10 12843 8598 K-5 12943 8658 HRZ 13338 8893 Kalubik 13422 8943 Kuparuk 13489 8983 Minimum required MW 9.9 ppg Base Kupamk 13746 9136 Evaluation Program: SURFACE Anadrill directional MWD only PRODUCTION CASED HOLE LOGS In hole reference gyro. Anadrill MWD/GR/CDN/CDR from 150' above top Kuparuk to TD MAD pass on this run at 900 fph to top K-15 (5200' TVD) and continue MAD pass to surface at up to 1800 fph. Contingent Atlas triple combo. None Well Plan Summary AUG 1 5 199,5 Oil & Gas Cong. Commi~i~n '~.: gnoh0rage Page 1 Mud Program: Special design considerations LSND system will include addition of Xanvis for rheological properties. Lubricant may be added if torque increases. Add Soltex for fluid loss control. Open hole change-over to 3% KC1 above Kupamk. Surface Mud Properties: I SPUD DENSITY Marsh Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 8.7 300 40-60 30-60 60-80 9-10 15-25 9.5 150 30-40 20-30 40-60 9-10 < 15 Production Mud Properties: I LSND DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 9.8 8-15 25-30 5-15 10-20 9-10 4-12 10.4 8-15 25-30 8-12 <30 9-9.5 +/- 5 < 15 HTHP Open-hole change-over above Kuparuk Reservoir Production Mud Properties: 1 3% KC1 Polymer DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 10.2 to 10.4 8-15 25-30 8-12 10-20 9-9.5 5 < 12 HTHP Directional-. I KOP: 1400' MD Maximum Hole Angle: Close Approach Well: 53.41° , hold angle to TD, azimuth = 103° [ None I Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 94# H-40 WLD 80' GL 80/80 13-1/2" 10-3/4" 45.5# NT-80LHE BTC 4589' 41'/41' 4630'/3702' 9-7/8" 7-5/8" 29.7# USS 95 MBTC 13,188' 41'/41' 13229'/8828 9-7/8" 7-5/8" 29.7# NT-13Cr-80 NSCC 534' 1322978828' 13763'/9146' TBG 4-1/2" 12.6# NT-13Cr-80 NSCT 13,272' 41'/41' 1331378878' Disposal: All fluids and cuttings to be hauled to C22A. Annular Injection (apart from freeze protection) is not allowed on P2 pad. Well Plan Summary Page 2 P2-37 Drilling Hazards/Risks Tight hole has been experienced in the lower Sagavanirktok formation, in wells where surface casing was set above the SV4 sand. This has caused stuck pipe incidents and bit/BHA balling Gumbo problems. ROP's in this section are typically very fast and care must be taken to ensure the hole does not become overloaded with cuttings. On well P2-07 the pipe stuck at a connection 4873' and a $380,000 BHA was lost, possibly due to insufficient hole cleaning. Recently drilled P2-28 experienced reduced hole problems and bit-bailing tendency by keeping fluid loss low and adding surfactant. Several faults have been identified in the target area, but with <20' of throw. These faults do not pose a drilling risk in the event of an intersection. A fault 900' to the north of target center is the nearest hazard identified. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. AUG 1 5 1995 Naska O[t & Gas Cons. Commission Anchorage Well Plan Summary Page 3 This second revision in the permit request includes a target shift of 500' to the west. The change in target was identified after obtaining the reservoir top from sidetrack well P. 2-50B. The reservoir top has since been re-defined for the area, making this new target a more viable option. We regret the inconvenience the permit changes have caused. Any questions regarding the permit should be directed to Phil Smith, Shared Services Drilling Engineer; 564-5475. o . , o o o . P2-37 Operations Summary MIRU drilling rig. NU and function test diverter. Spud well and drill 13-1/2" hole to 400' md. Kick off and build angle to 53.41° on 103° azimuth by 3117' md (2800' TVD). Hold angle to 4630' md (3702' TVD) surface hole TD. Set 10-3/4" casing and cement same. Test casing to 3000 psi for 10 minutes. Nipple up BOP's and test same to 5~000.psi. Note AOGCC witness or waiver on the morning report. P/U 9-7/8" BHA, drill 10' new hole and perform LOT. Drill ahead and hold 53.41° to TD at +13,672', (9146' TVD) 125' md below the pay. Perfrom open-hole change over to 3% KC1 polymer mud at 10.2 ppg before top of Kuparuk. Obtain LWD logs through Kupamk. POH and stand back drill pipe. Run 7-5/8" NT-13Cr-80 x USS95 casing (Crossover chrome to carbon steel +_250' above the reservoir) and cement same, displacing plug with seawater, check floats. Test casing to 4000 psi for 30 minutes. Run 4-1/2" NT-13Cr-80 tie-back string/completion assembly. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. Displace tubing to diesel, freeze protect the annulus. Set production packer. Test tubing and annulus to 4000 psi. Secure well, release rig. Well Plan Summary Page 4 ISu '~ String Surface string cement based onshoe volume ~lus 375 sacks of tail slurry, Pl~s lead to surface, both slurries with 70% excess. Spacer 7 5 bbls Fresh water LEAD (TYPE 'E' PERMAFROST) Volume 1130 Sacks (2451 fl3) (437 bbls) Casing depth 4630 ft Length 3963 ft Casing size 10.75 in Yield 2.17 ft3/sack Casing ID 9.95 in Density 1 2 PPg Casing weight 45.5 Ib/ft TOC 40 ft MD Bit diameter 13.5 in Mix water 11.55 gps 50° - 65° Fresh Excess factor 1.7 Thicken time 4 hrs - -~ '- Shoe track 8 0 f t C~RCTEMP 5 0!Deg F !TALL (Class 'G' + 2% CaCl2 accelerator Top of Lead 40 ft Volume 375 Sacks (431 ft3) (77 bbls) Top of Tail 4003 ft Length 627 ft Yield 1.15 Density 15.8 ppg TOC 4003 ft Mix water 5 gal/sk Fresh Thicken time 3.5 hrs TOP JOB (Type 'C' PERMAFROST) Volume 250 Sacks (266 ft3) (47 bbls) Yield 0.94 ft3/sack Density 15.6 ppg Mix water 3.7 gal/sk Fresh Production String I Base cement volume on 1000' above the Kuparuk reservoir plus 25% excess. Adjust volume iaccordingly. Lab test cement/spacer/mud program to ensure compatibility before job. i Ensure thickening times are adequate relative to pumping job requirement. Displace at maximum rate without inducing losses (10-12 bbl/min) Preflush 2 0 bbls Fresh water Spacer 7 0 bbls NSCl SPACER LEAD (Class 'G' +3% Econolite) Volume 0SacksI (0 ft3) (0 bbls) Additives: 0.4% CFR3 dispersant 2.0% HALAD 344 Fluid loss Casing depth 13763 ft Length 0 ft Casing size 7.625 in Yield 3.24 ft3/sack Casing ID 6.875 in Density 1 I ppg Casing weight 29.7 Ib/ft TOC 1 2500 ft MD Bit diameter 9.875 in Excess factor 1.25 TAIL (CLASS G' Premium) Shoe track 80 ft Volume 313 Sacks (360 ft3) (64 bbls) CIRCTEMP 140 Deg F Additives: I0.2% CFR3 dispersant Top of Lead 12500 0.4% HALAD 344 Fluid loss Top of Tail 12500 ft 0.15% HR-5 Length 1263 ft Yield 1.1 5 ft3/sack Density i 5.8 ppg TOC 12500 ft MD Thicken time 4-5 hrs AUG 1 5 199,5 Oil & Gas Cons. Commission = ~ch0rage AUG 1 5 1995 ~ .Nas~ OiL & Gas Cons. Commission ~chorage ........ SURFACE LOCATION Y, Sg98La97,,~$ / · TONY KNOWLE$, GOVERNOR ALAS OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 10, 1995 Steve Shultz, Senior Drlg. Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Pt Mclntyre P2-37 Revisedv BP Exploration (Alaska), Inc. 95-106 287'SNL, 1342'EWL, Sec 14, T12N, R14E, UM 2478'SNL, 647'EWL, Sec 18, T12N, R15E, UM Dear Mr Shultz: Enclosed is the approved revised application for permit to drill the above referenced well. 95, are in effect for this revision. David W JQ?'nston \ ~hairman '~ BY ORDER OF T MISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 REVISION - 08/07/95 la. Type of work Drill [] Redrill FIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] - Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 52 feet Point Mclntyre 3. Address 6. Property Designation P. O. Box 196612. Anchorac/e. Alaska 99519-6612 ADL 034627 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 287' SNL, 1342' EWL, SEC 14, T12N, R14E, UM Point Mclntyre .. At top of productive interval 8. Well number Number 2427' SNL, 406' EWL, SEC 18, T12N, R15E, UM P2-37 U-630610 At total depth 9. Approximate spud date Amount 2478'SNL, 647' EWL, SEC 18, T12N, R15E, UM 08/11/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(uDandTVD) property line ADL 034624 647 feet No Close Approach feet 2560 14150' MD/9089' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 3co MD feet Maximum hole angle 55 o Maximum surface 3330 psig At total depth (TVD) 8800't/43~)0 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 WLD 80' Surface Surface 80' 80' 160 sx AS (Approx.) 13-1/2" 10-3/4" 45. 5# NT-8OLHE BTC 4657' 41' 41' 4698' 3702' 1150 sx PF 'E', 375 sx 'G', 250 sx PF 'C' 9-7/8" 7-5/8" 29.7# USS95 MBTC 13509' 41' 41' 13550' 8748' 9-7/8" 7-5/8" 29.7# ~-~3cr. soNSCC 600' 13550 8748' 14150' 9089' 322 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary TOtal depth: measured feet Plugs (measured) true vertical feet Effective-depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface . Intermediate Production AUG 0 7 1995 Liner Perforation depth: measured ,A~3S~ {iii & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time Vs depth pict [] Refraction analysis[-! Seabed report[] 20/,A,~A~/2,~..'050 requirements[] 21.1 hereb~y that th~d_.~g is~t~/~ a/~ correct to the best of my knowledge ~///~/? Signed~ / / ~ ../¢'. _/¢zz~7'~"--- Title Senior Drilling Engineer. Date ~'~ -"- (.,/' c,,' ' '"'~Commission Use Only '. Permit Number IAPI number Approval date ISee coverJletter 95-106 150-029_22576 07/26/95 Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes ~ No Hydrogen sulfide measures ~ Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOPE []2M; 1-13M; 1~SM; 1-110M; I-I15M; Other: Original Signed 8~ by order of Approved by David W. Johnstor, Commissioner tne commission Date¢/¢o//~<~ Form 10-401 Rev. 12-1-85 Submit ir [Well Name: 1P2-37 Well Plan Summary I Type of Well (producer or injector): ] Producer Surface Location: 287' FNL, 1342' FWL, Sec. 14, T12N, R14E UM Target Location: 2427' FNL, 406' FWL, Sec. 18, T12N, R15E UM Bottom Hole Location: 2478' FNL, 647' FWL, Sec. 18, T12N, R15E UM I AFE Number: 12C0077 I I Estimated Start Date: I Rig: [Pool #7 8/11/95 I I Operating days to complete: I 24 MD: 114150 I ITVD: Well Design (conventional, slimhole, etc.): [ 9089' rkb I IKBE: 152' I [ Slimhole longstring Objective: [ Pt. Mclntyre eastern flank producer Formation Markers: Formation Tops MD TVD(BKB) Base Permafrost 1826 1787 K-15 7312 5192 West Sak 10496 7007 Minimum required MW 9.5 ppg K-10 13288 8598 K-5 13393 8606 HRZ 13691 8828 Kalubik 13779 8878 Kuparuk 13849 8918 Minimum required MW 9.9 ppg Base Kupamk 14118 9071 Evaluation Program: SURFACE Anadrill directional MWD only PRODUCTION In hole reference gyro. Anadrill MWD/GR/CDN/CDR from 150' above top Kupamk to TD MAD pass on this run at 900 fph to top K-15 (5200' TVD) and continue MAD pass to surface at up to 1800 fph. Contingent Atlas triple combo. CASED HOLE None LOGS Well Plan Summary Page 1 Mud Program: Special design considerations LSND system will include addition of Xanvis for rheological properties. Lubricant may be added if torque increases. Add Soltex for fluid loss control. Open hole change-over to 3% KC1 above Kuparuk. Surface Mud Properties: I SPUD DENSITY Marsh Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 8.7 300 40-60 30-60 60-80 9-10 15-25 9.5 150 30-40 20-30 40-60 9-10 < 15 Production Mud Properties: I LSND DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 9.8 8-15 25-30 5-15 10-20 9-10 4-12 10.4 8-15 25-30 8-12 <30 9-9.5 +/- 5 < 15 HTHP Open-hole change-over above Ku£aruk Reservoir Production Mud Properties: I 3% KC1 Polymer DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 10.2 to 10.4 8-15 25-30 8-12 10-20 9-9.5 5 < 12 HTHP Directional: I KOP: 1300' MD I Maximum Hole Angle: Close Approach Well: 55 , hold angle to TD, azimuth = 102.5° I None Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDfrVD MDfrVD 30" 20" 94# H-40 WLD 80' GL 80/80 13-1/2" 10-3/4" 45.5# NT-80LHE BTC 4657' 41'/41' 4698'/3702' 9-7/8" 7-5/8" 29.7# USS 95 MBTC 13,509' 41'/41' 13550'/8748 9-7/8" 7-5/8" 29.7# NT-13Cr-80 NSCC 600' 13550'/8748' 14150'/9089' TBG 4-1/2" 12.6# NT-13Cr-80 NSCT 13,700' 41'/41' 1369178828' Disposal: All fluids and cuttings to be hauled to C22A. Annular Injection (apart from freeze protection) is not allowed on P2 pad. Well Plan Summary AUG 0 7 199,5 Alaska Oil I Gas Cons. CommTss/on Anchorage Page 2 P2-37 Drilling Hazards/Risks Tight hole has been experienced in the lower Sagavanirktok formation, in wells where surface casing was set above the SV4 sand. This has caused stuck pipe incidents and bit/BHA balling Gumbo problems. ROP's in this section are typically very fast and care must be taken to ensure the hole does not become overloaded with cuttings. On well P2-07 the pipe stuck at a connection 4873' and a $380,000 BHA was lost, possibly due to insufficient hole cleaning. Recently drilled P2-28 experienced reduced hole problems and bit-bailing tendency by keeping fluid loss Iow and adding surfactant. Several faults have been identified in the target area, but with <20' of throw. These faults do not pose a drilling risk in the event of an intersection. A fault 900' to the north of target center is the nearest hazard identified. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. AUG 0 7 1995 Oil & Gas Cons, Commis~lon Well Plan Summary Page 3 The requested casing design for P2-37 has been changed from monobore (9-5/8" surface, 4-1/2" liner/tubing) to 7-5/8" slimhole Iongstring. This revised permit request reflects the changes. The drilling target has not changed, but the rathole has been reduced, shifting TD higher and the TD coordinates back northwest along the wellbore 70'. Any questions regarding the permit should be directed to Phil Smith, Shared Services Drilling Engineer; 564-5475. , o , o o . o P2-37 Operations Summary MIRU drilling rig. NU and function test diverter. Spud well and drill 13-1/2" hole to 400' md. Kick off and build angle to 55.25° on 102.7° azimuth by 3191' md (2843' TVD). Hold angle to 4698' md (3702' TVD) surface hole TD. Set 10-3/4" casing and cement same. Test casing to 3000 psi for 10 minutes. Nipple up BOP's and test same to 5000 psi. Note AOGCC witness or waiver on the morning report. P/U 9-7/8" BHA, drill 10' new hole and perform LOT. Drill ahead and hold 55.25° to TD at +14150', (9089' TVD) 125' md below the pay. Perfrom open-hole change over to 3% KC1 polymer mud at 10.2 ppg before top of Kuparuk. Obtain LWD logs through Kuparuk. POH and stand back drill pipe. Run 7-5/8" NT-13Cr-80 x USS95 casing (Crossover chrome to carbon steel 300' above the reservoir) and cement same, displacing plug with seawater, check floats. Test casing to 4000 psi for 30 minutes. Run 4-1/2" NT-13Cr-80 tie-back string/completion assembly. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. Displace tubing to diesel, freeze protect the annulus. Set production packer. Test tubing and annulus to 4000 psi. Secure well, release rig. Well Plan Summary Page 4 P2-37 SH cement Cement Supplier: Halliburton I Surface string Surface string cement based onshoe volume plus 375 sacks of tail slurry, plus lead to surface, both slurries with 70% excess. I III I Spacer 7 5 bbls Fresh water ! I LEAD (TYPE 'E' PERMAFROST) I Volume 1150 Sacks (2495 ft3) I I (444 bbls) Casing depth 4700 ft ILength I 4033 ft Casing size 10.75 in IYieldI 2.17 ft3/sack Casing ID 9.95 in Density 1 2 ppg Casing weight] 45.5 Ib/ft TOC 40 ft MD Bit diameter 13.5 in IMix water ]11.55 gps 50° - 65° Fresh Excess factor 1.7If ]Thicken time '4 hrs Shoe track 80 t CIRCTEMP I 5 0 Deg FJTAIL (Class 'G' + 2% CaCl2 accelerator ) Top of Lead I 401ft IVolume i 375 Sacksi (431 ft3) (77 bbls) Top of TailI 4073 ft ILength I 627 ft I Yield I 1.15 Density 15.8 ppg iTOC 4073 ft I Mix water 5 gal/sk Fresh Thicken time 3.5 hrs I ]TOP JOB I (Type 'C' PERMAFROST) I ]Volume I 250 Sacksl (266 ft3) (47 bbls) I ]Yield I 0.941ft3/sack ]Density 15.6 ppg I i Mix water 3.7 gal/sk Fresh I I I I Production String I I I Base cement volume on 1000' above the Kuparuk reservoir plus 25% excess. Adjust volume accordingly. Lab test cement/spacer/mud program to ensure compatibility before job. Ensure thickening times are adequate relative to pumping job requirement. I __ Displace at maximum rate without inducing losses (10-12 bbl/min) I IPreflushI 2 0 bbls Fresh water II i]Spacer ii 7 0 bbls NSCI SPACER -- i I LEAD (Class 'G' +3% Econolite) ! Volume 0SacksI (0 ft3) (0 bbls)_ I Additives: 0.4% CFR3 dispersant fl 2.0% HALAD 344 Fluid loss I I of Casing depth ! 14150 ft Length t Casing size I 7.625 ~n Yield 3.24 ft3/sack Casing ID i 6.875 ~n Density I 1 1 ppg Casing weight 29.7 b/ft TOC G' 12850 ft MD Bit diameter 9.875 ~n Excess factor i 1.25 TAIL (CLASS Premium) Shoe track I 80irt Volume I 322 Sacks (370 ft3) (66 bbls) CIRCTEMP I 1 40iDeg F Additives: 0.2% CFR3 dispersant Top of Lead 1 2850i 0.4% HALAD 344 Fluid loss Top of Tail 128501ft 0.15% HR-5 0 ! I Length 130 ft i ! Y e d 1.1 5 ft3/sack --- I I IDensity 1 5.8 ppg I [ ITOC 12850 ff MD -- I I IThicken time 4-5 hrs Aiask State Plane: Zone4 ~. HALLIBURTON Pt ~a~ ' PMg P2-37 As-Bu~t P2-37 ~p4 .~ ~.~"~ ~. s,.' ,oL.. 700 E J .r ~ ~4.~' ~,70' 1787 261 'e'~ ~'' '-~'' ~,~1'7007 LOCATION 1 ALASKA OIL AND GAS 'CONSERVATION COM~HSSION ! / ! TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 26, 1995 Steve Shultz, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Pt. Mclntyre P2-37 BP Exploration (Alaska), Inc. Permit No 95-106 Surf Loc 287'SNL, 1342'EWL, Sec. 14, T12N, R14E, UM Btmhole Loc 2488'SNL, 716, EWL, Sec. 18, T12N, R15E, UM Dear Mr Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be ifield inspector 059-3607. · DavTd-w. J--6h)sto n ~ /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 Type of work Drill [] Redrill[~llb. Type of well. Exploratory[Z] Stratigraphic Test[] Development Oilrk-1 Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 52 feet Point Mclntyre 3. Address 6. Property Designation P. O. Box 196612, Anchoraqe, Alaska 99519-6612 ADL 034627 !4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 287' SNL, 1342' EWL, SEC 14, T12N, R14E, UM Point Mclntyre At top of productive interval 8. Well number Number 2427' SNL, 406' EWL, SEC 18, T12N, R15E, UM P2-37 U-630610 At total depth 9. Approximate spud date Amount 2488' SNL, 716' EWL, SEC 18, T12N, R15E, UM 07/30/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 034624 716 feet No CloseApproach feeti 2560 14192'MD/9139'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 300 Ma feet Maximum hole angle 5~ o Maximum sudace 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 WLD 80' Surface Surface 80' 80' 160 sx AS (Approx.) 12-1/4" 9-5/8" 47# NT-80 NSCC 6925' 41' 41' 6966' 5000' 1517 sx PF'E', 3755x 'G; 250 sx PF'C' 8-1/2" 4-1/2" 12.6# VT-13Cr-80NSCT 7376' 6816' 4914' 14192' 9139' 810 sx Class 'G' !19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surfaoe RECEIVED Intermediate Production JUL 1 4 1995 Liner Perforation depth: measured Alaska 0il & Gas Cons, Commission true vertical Anchor~ 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-1 20 AAC 25.050 requirements[] 21. I hereby _~.-.-.-.-.-.-.-.-.~. ify th Signed ~_~ ~"~6~ f° reg~)n ~ is ~?~~~nd cOrrect tO the best Of my knOwledge t"¢,.._.,/') /q ~, Ti tl e Senior Drilling Engineer Date .~"' Commission Use Only Permit Number APl number Approval date See cover letter /O,~',.,-//~oC,~' 50- O.2_,~ --- .~. 2_. O~',~' "¢J ~, ~ "~,~" for other requirements Cor~ditions of approval Samples required [] Yes ~ No Mud Icg required []Yes ~ No Hydrogen sulfide measures ,,~ Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; 1-13M; I~5M; I'-I10M; FI15M; Other: Original Signed By by order of Approved by n~vid W. Johnston Commissioner ,ne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate I Well Name: IP2-37 Well Plan Summary ] Type of Well (producer or injector): ] Producer Surface Location: 287' FNL, 1342' FWL, Sec. 14, T12N, R14E UM Target Location: 2427' FNL, 406' FWL, Sec. 18, T12N, R15E UM Bottom Hole Location: 2488' FNL, 716' FWL, Sec. 18, T12N, R15E UM I AFE Number: [2C0077 ] Estimated Start Date: ] 7/30/95 Rig: I Pool #7 Operating days to complete: [ 19 I MD: ] 14192' ] I TVD: 19139'rkb [ [KBE: ] Well Design (conventional, slimhole, etc.): ] ultra slimhole monobore [52' I Objective: [ Pt. Mclntyre eastern flank producer Formation Markers: Formation Tops MD TVD(BKB) Base Permafrost 1813 1787 K-15 6765 5192 West Sak 9771 7007 Minimum required MW 9.5 ppg K-10 12646 8598 K-5 12662 8658 HRZ 12826 8828 Kalubik 12876 8878 Kuparuk 12909 8918 Minimum required MW 9.9 ppg Base Kupamk 13245 9071 Evaluation Program: SURFACE Anadrill directional MWD only PRODUCTION CASED HOLE LOGS In hole reference gyro. Anadrill MWD/GR/CDN/CDR from 150' above top Kuparuk to TD MAD pass on this run at 900 fph to top K-15 (5200' TVD) and continue MAD pass to surface at up to 1800 fph. Contingent Atlas triple combo. None Well Plan Summary Gas Cons. {;ommission Page 1 Mud Program: Special design considerations LSND system will include addition of Xanvis for rheological properties. Lubricant may be added if torque increases. Add Soltex for fluid loss control. Open hole change-over to 3% KC1 above Kupamk. Surface Mud Properties: [SPUD DENSITY Marsh Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 8.7 300 40-60 30-60 60-80 9-10 15-25 9.5 150 30-40 20-30 40-60 9-10 <15 Production Mud Properties: [ LSND DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 9.8 8-15 25-30 5-15 10-20 9-10 4-12 10.4 8-15 25-30 8-12 <30 9-9.5 +/- 5 < 15 HTHP Open-hole change-over above Kuparuk Reservoir Production Mud Properties: [ 3% KC1 Polymer DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 10.2 to 10.4 8-15 25-30 8-12 10-20 9-9.5 5 < 12 HTHP Directional: [KOP: 1 300' MD Maximum Hole Angle: Close Approach Well: 55 , hold angle to TD, azimuth = 102.7° None Casing/Tubing Program: Hole Size Cs#/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 94# H-40 WLD 80' GL 80/80 12-1/4" 9-5/8" 47# NT-80 NSCC 6925' 41 '/41' 6966'/5000' Liner 8-1/2" 4-1/2" 12.6# NT-13Cr-80 NSCT 7376' 6816'/4914' 14192'/9139' TBG 4-1/2" 12.6# NT-13Cr-80 NSCT 6774' 41'/41' 6816'/4914' Disposal: notAll all owedflUids andonCUttingSp2 pad.t° be hauled to C22A. Annular Injection~ E [ ~[(a-p'a'rt'frt)¢V ~ freeze protection) is jUL i 4 I .S5 Well Plan Summary Alaska Oil & Gas Cons. Oommission AllcllO;? ' Page 2 P2-37 Drilling Hazards/Risks Tight hole has been experienced in the lower Sagavanirktok formation, in wells where surface casing was set above the SV4 sand. This has caused stuck pipe incidents and bit/BHA balling Gumbo problems. It is also likely to be a problem in this 12-1/4" surface hole. ROP's in this section are typically very-fast and care must be taken to ensure the hole does not become overloaded with cuttings. On well P2-07 the pipe stuck at a connection 4873' and a $380,000 BHA was lost, possibly due to insufficient hole cleaning. Recently drilled P2-28 experienced reduced hole problems and bit-bailing tendency by keeping fluid loss low and adding surfactant. Sveral faults have been identified in the target area, but with <20' of throw. These faults do not pose a drilling risk in the event of an intersection. A fault 900' to the north of target center is the nearest hazard identified. This will be the first producer to use the 'Monobore' well design. The drilling program is essentially the same as that for our slimhole longstring wells, with the exceptions that a) the surface casing is set at 5000' TVDSS instead of 3650' TVDSS, and b) the production casing is run as a liner and tieback instead of a longstring. The main difference for this monobore well design is the proposed well completion, which is a string of 4-1/2" tubing used to tie back the 4-1/2" liner to surface. This tubing will have a seal mandrel at the bottom which will sting into a PBR at the liner top. Pressure integrity of this string will be verified. A risk analysis has been performed on this new type of well which has been designed to meet BPX Drilling and Casing Design Policies. The risks and concerns expressed by corrosion problems have been mitigated by the well design and the design has been approved by the field owners. Corrosion issues were addressed separately by detailed study work and have been discussed with the AOGCC Commisioners. They were summarized in a letter.sent from Mr. G. Phillips to Mr. B. Wondzell, dated April, 13, 1995. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Well Plan Summary Page 3 P2-37 Operations Summary 1.. MIRU drilling rig. NU and function test diverter. . Spud well and drill 12-1/4" hole to 300' md. Kick off and build angle to 55.06° on 102.7° azimuth by 3243' md (2868' TVD). Hold angle to 6966' md (5000' TVD) surface hole TD. o . · Set 9-5/8" casing and cement same. Test casing to 3000 psi for 10 minutes. Nipple up BOP's and test same to 5000 psi. Note AOGCC witness or waiver on the morning report. P/U 8 -1/2" BHA, drill 10' new hole and perform LOT. Drill ahead and hold 55.06° to TD at _+14192', (9139' TVD) 125' md below the OWC. Perfrom open-hole change over to 3% KC1 polymer mud at 10.2 ppg before top of Kuparuk. Obtain LWD logs through Kupamk. o POH and stand back drill pipe. Run 4-1/2" NT-13Cr-80 liner and cement same, set liner top packer. Test casing to 4000 psi for 30 minutes. o RIH and clean out liner/displace to seawater. POH, GIH with PBR polishing mills and polish liner tieback sleeve, POH 7. Run 4-1/2" NT-13Cr-80 tie-back string/completion assembly. o Displace tubing to diesel, freeze protect the annulus. Sting liner tieback seals into liner top. Test tubing and annulus to 4000 psi. 9. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. 10. Secure well, release rig. POST RIG WORK 1. Run cased hole logs: cement bond log. Well Plan Summary Page 4 Cement Spreadsheet Cement Supplier: Halliburton Surface string must be fully cemented to the surface. This cdteda is essential for the success of the well. Check top job after the cement sets to ensure it hasn't fallen. Repeat the top job if necessary. Sudace String Spacer 7 5 bbls Fresh water Volume 1517 Sacks (3291 ft3) (586 bbls) Casing depth 6966 ft Length 6178 ft Casing size 9.625 in Yield 2,17 ft3/sack Casing ID 8.681 in Density 1 2 PPg Casing weight 47 Ib/ft TOC 40 ft MD Bit diameter 12.25 in Mix water 11.55 gps 50° - 65° Fresh Excess factor 1.7 Thicken time 4 hrs Shoe track 8 0 f t ClRCTEMP 50 Deg F TAIL (Class 'G' + 2% CaCl2 accelerator Top of Lead 40 ft Volume 375 Sacks (431 ft3) (77 bbls) Top of Tail 621 8 ft Length 748 ft !Yield 1.15 Density 15.8 ppg TOC 621 8 ft Mix water 5 gal/sk Fresh Thicken time 3.5 hrs TOP JOB (Type 'C' PERMAFROST) Volume 250 Sacks (266 ft3) (47 bbls) Yield 0.94 ft3/sack Density 15.6 ppg Mix water 3.7 gal/sk Fresh Casing depth 14192 ft Production String Casing size 4.5 in Casing ID 4.892 in Preflush 20 bbls Fresh water Casing weight 1 7 I b/ft Spacer 7 0 bbls NSCI SPACER Bit diameter 8.5 in Excess factor 1.25 LEAD (Class 'G' +3% Econolite) Shoe track 80 ft Volume 528 SacksI (1711 ft3) (305 bbls) CIRCTEMP 1 40 Deg F Additives: 0.4% CFR3 dispersant Top of Lead 8482 2.0% HALAD 344 Fluid loss Top of Tail 13306 ft Length 48241ft Yield 3.24 ft 3/s ac k Density 1 1 PPg TOC 8482 ft MD TAIL (CLASS G' Premium) Volume 282 Sacks; (325 ft3) (58 bbls) Additives: 0.2% CFR3 dispersant 0.4% HALAD 344 Fluid loss 0.15% HR-5 Length 886 ft Yield 1.1 5 ft3/sack Density 1 5.8 ppg TOC 1 33061ft MD Thicken time 4-5 hrs 'vERT~C~K_' SCALE ~ ri:, / DIVISIgW TVD t::~::~SF: WELLHEAD VERTICAL SECT10N REF: WELLHEAD O-- 1193 1749 · 712130-- P/t7/c~s 11:44 om BPX-Shamed SePvices ]3Piiling ~ Alaska Sta±e Plane', Zone4 ~ ~,,~Bi S±muctume '. Pt Mac'. PMB Slot'. Pa-37 ~eilpoth : P8-37 Wp~ ~~T~ VIEW (TRUE NBRTH) ~ 8/17/~ ~46 ~ ~E 50E ft. / SIV]Si~N ~ 4000 V~ !0t~76 WELL PERMIT CHECKLIST o COMPANY INIT CLASS dev~ redrll [] ON/OFF SHORE serv [] ADMINISTRATION 1. Permit fee attached ................... y 2. Lease number appropriate ............... 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ...... N 8. If deviated, is wellbore plat included ......... N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order ..... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ........ N ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg.~ N 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.~----~-- 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~~ N 26. BOPE press rating adequate; test to ~~ pslg.(_~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N~ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... /. Y N · . Y N 34. Contact name/phone for weekly progress reports . .,>~ [exploratory only] ENGINEERING: COMMISS ION: Comments/Instructions: HOW/Jo - A:~FORMSlcheklist rev 03/94 WELL PERMIT CHECKLIST COMPANY INIT CLASS ~m~t,, /-,,~?'/ ADMINISTRATION 1. Permit fee attached ................... N 2. Lease number appropriate ................ N 3. Unique well name and number ............... N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ...... N ' 7. Sufficient acreage available in drilling unit ...... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING APPR DATE 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg.. ~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a' 10-403 for abndnmnt been approved. ~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... .I'~.~~ N 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~OcD~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N~_ 31. Seismic analysis 9f shallow gas zones .......... Y/ Data presented on potential overpressure zones ..... 32. 33. Seabed condition survey (if off-shore) ....... ~/Y 34. Contact name/phone for weekly progress reports . . ~/.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: O HOW/jo - A:~ORMS~heklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : P2-37 FIELD NAME : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292257600 REFERENCE NO : 95312 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-SEP-1995 12:05 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/09/28 ORIGIN : FLIC REEL NAME : 95312 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., POINT MCINTYRE P2-37, API #50-029-22576-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 95/09/28 ORIGIN : FLIC TAPE NAME : 95312 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : ARCO ALASKA INC., POINT MCINTYRE P2-37, API #50-029-22576-00 TAPE HEADER POINT MCINTYRE MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD P2-37 500292257600 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 28-SEP-95 1ST STRING 2ND STRING 95312 ST. AMOUR LES PEAK BIT RUN 2 BIT RUN 3 14 12N 14E 287 1342 51.50 51.50 11.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 4624.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-SEP-1995 12:05 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE LDWG FORMATTED DATA FOR POINT MCINTYRE P2-37. THE TOOLS LOGGED ARE ANADRILLS CDR AND CDN. THERE IS i MWD INTERVAL AND 2 MAD INTERVALS. $ **** FILE HEADER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves~ all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 13400.0 13814.0 CDN 13400.0 13814.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH CDR 88888.0 88887.0 13651.5 13650.5 13631.0 13629.5 13623.0 13622.5 13611.5 13611.0 13608.0 13609.0 13607.0 13607.0 13575.5 13575.0 13558.0 13557.5 13544.5 13544.0 13541.5 13541.0 13536.0 13535.5 13530.0 13528.0 13517.5 13515.5 13514.5 13513.0 13496.5 13494.0 13480.0 13478.5 CDN LIS Tape Verification Listing Schlumoerger Alaska Computing Center 28-SEP- 1995 12:05 13465.5 13460.0 13457.0 13451.5 13432.5 13428.0 13402.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ 13463.5 13459.5 13455.0 13449.5 13431.0 13426.5 13400.5 BIT RUN NO. MERGE TOP MERGE BASE REMARKS: THIS FILE CONTAINS THE DEPTH CORRECTED AND CLIPPED CDR AND CDN DATA FOR THE MWD DRILLED INTERVAL. $ LIS FORMAT DATA PAGE: 3 TABLE TYPE : CONS TUN I VALU .................................... ............... FN POINT MCINTYRE WN P2-37 APIN 500292257600 FL 0287 FNL 1342 FWL SECT 14 TOWN 12N RANG 14E COUN NORTH SLOPE STAT ALASKA NATI USA LATI 70 24 02N LONG 148 31 19W WITN LES PEAK SON 52154 PDAT MEAN SEA LEVEL EPD FT O. LMF DRILL FLOOR APD FT 51.5 EKB FT 51.5 EDF FT 51.5 EGL FT 11.5 TDD FT 13815. TDL FT 13815. BLI FT 13815. TLI ' FT 4544. DFT KCL POLYMER DFD G/C3 10. DFV S 55. RMS OHMM 0.215 DEFI Company Name Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Latitude Longitude Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Drilling Fluid Density Drilling Fluid Viscosity Resistivity of Mud Sample LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-SEP-1995 12:05 PAGE: 4 TUNI VALU DEFI MST DEGF 70. Mud Sample Temperature RMFS OHMM 0.205 Resistivity of Mud Filtrate S MFST DEGF 70. Mud Filtrate Sample Temperatu RMCS OHMM 0.264 Resistivity of Mud Cake Sampl MCST DEGF 70. Mud Cake Sample Temperature BHT DEGF 150. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY ENHANCED PHASE RESISITIVTY DER DIELECTRIC RESISITIVTY ROP RATE OF PENETRATION FET TIME AFTER BIT GR Gamma Ray RHOB Bulk Density DRHO Delta RHO PEF PhotoElectric Factor CALN NUCLEAR CALIPER NPHI Thermal Neutron Porosity GRCH GAMMA RAY IN CASING ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-SEP- 1995 12:05 PAGE: TYPE REPR CODE VALUE 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) oo ooo oo o RA MWD OHMM 52154 O0 000 O0 0 1 i 1 4 68 0000000000 RP MWD OHMM 52154 O0 000 O0 0 i i I 4 68 0000000000 VRA MWD OHMM 52154 O0 000 O0 0 I 1 1 4 68 0000000000 VRP MWD OHMM 52154 O0 000 O0 0 i i 1 4 68 0000000000 DER MWD OHMM 52154 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPNR 52154 O0 000 O0 0 i i 1 4 68 0000000000 FET MWD HR 52154 O0 000 O0 0 i i i 4 68 0000000000 GR MWD GAPI 52154 O0 000 O0 0 I 1 1 4 68 0000000000 RHOB MWD G/C3 52154 O0 000 O0 0 1 i I 4 68 0000000000 DRHO MWD G/C3 52154 O0 000 O0 0 i i 1 4 68 0000000000 PEF MWD BN/E 52154 O0 000 O0 0 1 1 1 4 68 0000000000 CALN MWD IN 52154 O0 000 O0 0 1 i 1 4 68 0000000000 NPHI MWD PU-S 52154 O0 000 O0 0 I I 1 4 68 0000000000 GRCH CBT GAPI 52154 O0 000 O0 0 I i I 4 68 0000000000 ** DATA ** DEPT. 13814.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 16.851 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 GRCH.CBT -999.250 DEPT. 12924.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 GRCH.CBT 55.473 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumoerger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE ; FLIC VERSION : 001C01 DATE : 95/09/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 28-SEP-1995 12:05 PAGE: FILE HEADER FILE NUMBER: 2 EDITED MAD PASSES Depth shifted and clipped curves~ for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH CDR 4544.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 12070.0 BASELINE DEPTH 88888.0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... CDR 88886.0 98.0 REMARKS: THIS FILE CONTAINS THE DEPTH CORRECTED DATA OF MAD RUN #1. THE BASE GRCH.CBT ONLY COVERS THE INTERVAL FROM 13662' TO 12924', THEREFORE THERE IS ONLY A CONSTANT BLOCKSHIFT OF -2' OVER THE INTEVAL OF MAD RUN #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-SEP-1995 12:05 PAGE: 7 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN POINT MCINTYRE Field Name WN P2-37 Well Name APIN 500292257600 API Serial Number FL 0287 FNL 1342 FWL Field Location SECT 14 Section TOWN 12N Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation LATI 70 24 02N Latitude LONG 148 31 19W Longitude WITN LES PEAK Witness Name SON 52154 Service Order Number PDAT MEAN SEA LEVEL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 51.5 Above Permanent Datum EKB FT 51.5 Elevation of Kelly Bushing EDF FT 51.5 Elevation of Derrick Floor EGL FT 11.5 Elevation of Ground Level TDD FT 13815. Total Depth - Driller TDL FT 13815. Total Depth Logger BLI FT 13815. Bottom Log Interval TLI FT 4544. Top Log Interval DFT KCL POLYMER Drilling Fluid Type DFD G/C3 10. Drilling Fluid Density DFV S 55. Drilling Fluid Viscosity RMS OHMM 0.215 Resistivity of Mud Sample MST DEGF 70. Mud Sample Temperature RMFS OHMM 0.205 Resistivity of Mud Filtrate S MFST DEGF 70. Mud Filtrate Sample Temperatu RMCS OHMM 0.264 Resistivity of Mud Cake Sampl MCST DEGF 70. Mud Cake Sample Temperature BHT DEGF 150. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY ENHANCED PHASE RESISITIVTY DER DIELECTRIC RESISITIVTY GR Gamma Ray LIS Tape Verification Listing Schlumoerger Alaska Computing Center 28-SEP-1995 12:05 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ..... ..... i 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** ID ORDER # LOG TYPE CLASS MOO NUMB SAMP ELEM CODE (HEX) DEPT FT 52154 O0 000 O0 0 2 i i 4 68 0000000000 RA MAD OHMM 52154 O0 000 O0 0 2 1 1 4 68 0000000000 RP MAD OHMM 52154 O0 000 O0 0 2 1 i 4 68 0000000000 VRA MAD OHMM 52154 O0 000 O0 0 2 I i 4 68 0000000000 VRP MAD OHMM 52154 O0 000 O0 0 2 i I 4 68 0000000000 DER MAD OHMM 52154 O0 000 O0 0 2 1 i 4 68 0000000000 GR MAD GAPI 52154 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA DEPT. VRP.MAD DEPT. VRP.MAD 12070.000 RA.MAD 3.483 RP.MAD 3.587 VRA.MAD 3.653 DER.MAD 3.550 GR.MAD 92.506 4544.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD -999.250 DER.MAD -999.250 GR.MAD 75.063 3. 690 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 28-SEP-1995 12:05 PAGE: FILE HEADER FILE NUMBER: 3 EDITED MAD PASSES Depth shifted and clipped curves~ for each pass of each run in separate files. MAD RUN NUMBER: 2 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY LDWG TOOL CODE START DEPTH CDR 12070.0 CDN 13300.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH CDR 88888.0 88887.5 13396.5 13396.0 13388.0 13386.0 13379.5 13379.0 13374.5 13374.0 13371.5 13370.5 13367.0 13366.0 13359.0 13357.5 13353.5 13352.5 13345.5 13346.5 13340.0 13341.5 13334.0 13336.5 13331.0 13333.0 STOP DEPTH 13400.0 13400.0 ---EQUIVALENT UNSHIFTED DEPTH .......... CDN LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-SEP-1995 12:05 13323.5 13328.0 13319.5 13324.5 13305.0 13309.0 13297.5 13301.5 13287.5 13290.0 13276.0 13279.0 13270.0 13269.5 13266.5 13266.0 13265.0 13264.0 13244.5 13245.5 13235.5 13238.0 13227.5 13228.5 13203.5 13205.5 13190.0 13193.5 13185.0 13186.5 13179.0 13182.0 13172.5 13176.5 13168.5 13173.0 13164.0 13169.0 13160.0 13162.5 13152.0 13153.0 13142.0 13144.0 13138.5 13140.0 13128.5 13131.5 13126.0 13128.5 13122.0 13124.5 13115.0 13118.5 13104.0 13108.0 13102.0 13105.0 13097.5 13099.0 13087.5 13087.5 13076.5 13072.5 13062.0 13060.5 13055.0 13053.0 13052.5 13050.5 13038.5 13040.0 13032.5 13033.0 13028.5 13028.0 13021.0 13019.5 13014.0 13010.5 13003.5 13001.0 12998.0 12994.5 12986.5 12984.0 12969.0 12967.5 12964.5 12963.0 12932.5 12931.5 12930.0 12929.5 12928.5 12927.5 12927.0 12925.0 100.0 98.0 $, REMARKS: THIS FILE CONTAINS THE DEPTH CORRECTED DATA OF MAD RUN #2. THE BASE GRCH.CBT ONLY COVERS THE INTERVAL FROM 13662' TO 12924', THERE FOR ONLY A PORTION PAGE: 10 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-SEP-1995 12:05 OF MAD RUN #2 USES A GAMMA RAY TO GAMMA RAY DEPTH CORRELATION. MAD RUN #2 DATA ABOVE 12924' HAS A CONSTANT BLOCKSHIFT OF -2'. $ LIS FORMAT DATA PAGE: 11 TABLE TYPE : CONS TUNI VALU DEFI .................................... ............... ................... FN POINT MCINTYRE Field Name WN P2-37 Well Name APIN 500292257600 API Serial Number FL 0287 FNL 1342 FWL Field Location SECT 14 Section TOWN 12N Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation LATI 70 24 02N Latitude LONG 148 31 19W Longitude WITN LES PEAK Witness Name SON 52154 Service Order Number PDAT MEAN SEA LEVEL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 51.5 Above Permanent Datum EKB FT 51.5 Elevation of Kelly Bushing EDF FT 51.5 Elevation of Derrick Floor EGL FT 11.5 Elevation of Ground Level TDD FT 13815. Total Depth - Driller TDL FT 13815. Total Depth - Logger BLI FT 13815. Bottom Log Interval TLI FT 4544. Top Log Interval DFT KCL POLYMER Drilling Fluid Type DFD G/C3 10. Drilling Fluid Density DFV S 55. Drilling Fluid ViscositS RMS OHMM 0.215 Resistivity of Mud Sample MST DEGF 70. Mud Sample Temperature RMFS OHMM 0.205 Resistivity of Mud Filtrate S MFST DEGF 70. Mud Filtrate Sample Temperatu RMCS OHMM 0.264 Resistivity of Mud Cake Sampl MCST DEGF 70. Mud Cake Sample Temperature BHT DEGF 150. Bottom Hole Temperature LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-SEP-1995 12:05 TABLE TYPE : CURV DEFI DEPT Depth RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY ENHANCED PHASE RESISITIVTY DER DIELECTRIC RESISITIVTY GR Gamma Ray RHOB Bulk Density DRHO Delta RHO PEF PhotoElectric Factor CALN NUCLEAR CALIPER NPHI Thermal Neutron Porosity PAGE: 12 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** -¥~ ..... ~-~ ..... ~- I 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) -~-: ...... ~¥--~--~- ooo oo o ~~ ~ ~ ~ --~~--- RA MAD OHMM 52154 O0 000 O0 0 3 1 1 4 68 0000000000 ~p ~AD o,~ ~ oo ooo oo o ~ ~ ~ ~ 6~ oooooooooo VRA MAD OHMM 52154 O0 000 O0 0 3 1 1 4 68 0000000000 v~p ~ oH~ ~ oo ooo oo o ~ ~ ~ ~ 68 oooooooooo LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-SEP-1995 12:05 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE -~- PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DER MAD OHMM 52154 O0 000 O0 0 3 I I 4 68 0000000000 GR MAD GAPI 52154 O0 000 O0 0 3 I 1 4 68 0000000000 RHOB MAD G/C3 52154 O0 000 O0 0 3 I i 4 68 0000000000 DRHO MAD G/C3 52154 O0 000 O0 0 3 1 1 4 68 0000000000 PEF MAD BN/E 52154 O0 000 O0 0 3 1 1 4 68 0000000000 CALN MAD IN 52154 O0 000 O0 0 3 1 I 4 68 0000000000 NPHI MAD PU-S 52154 O0 000 O0 0 3 1 1 4 68 0000000000 13 ** DATA ** DEPT. 13400.000 RA.MAD 3.895 RP.MAD 3.715 VRA.MAD VRP.MAD 3.949 DER.MAD 3.771 GR.MAD 110.070 RHOB.MAD DRHO.MAD 0.031 PEF.MAD 7.045 CALN.MAD 11.104 NPHI.MAD DEPT. 12070.000 RA.MAD 3.483 RP.MAD 3.587 VRA.MAD VRP.MAD 3.653 DER.MAD 3.550 GR.MAD 92.506 RHOB.MAD DRHO.MAD -999.250 PEF.MAD -999.250 CALN.MAD -999.250 NPHI.MAD 3.873 2.204 37.366 3.690 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/09/28 ORIGIN : FLIC TAPE NAME : 95312 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., POINT MCINTYRE P2-37, API #50-029-22576-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-SEP-1995 12:05 PAGE: 14 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/09/28 ORIGIN : FLIC REEL NAME : 95312 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., POINT MCINTYRE P2-371API #50-029-22576-00